CN111749664B - Oil field whole-course chemical flooding combined take-over opportunity optimization method and system - Google Patents

Oil field whole-course chemical flooding combined take-over opportunity optimization method and system Download PDF

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CN111749664B
CN111749664B CN202010627494.1A CN202010627494A CN111749664B CN 111749664 B CN111749664 B CN 111749664B CN 202010627494 A CN202010627494 A CN 202010627494A CN 111749664 B CN111749664 B CN 111749664B
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chemical flooding
production
flooding
permeability
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CN111749664A (en
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曾杨
张健
康晓东
谢晓庆
梁丹
马若雨
未志杰
杨光
王旭东
杜庆军
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China National Offshore Oil Corp CNOOC
CNOOC Research Institute Co Ltd
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
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Abstract

The invention relates to an optimization method and a system for a whole-course chemical flooding combined succession opportunity of an oil field, which comprises the following steps: s1 determining the chemical flooding type and the sequence of the chemical flooding in the whole-course chemical flooding combination; s2 generating water content fw and dimensionless fluid production index J according to oil field parametersLDThe relationship model of (1); s3, obtaining a reasonable liquid production amount Q under any water content condition according to the production initial condition and the relation model of the oil production well; s4, establishing a plurality of oil reservoir numerical simulation models corresponding to different take-over moments according to the sequence of each chemical flooding in the whole-course chemical flooding combination and the reasonable liquid production amount Q; s5, calculating the recovery ratio of the numerical reservoir simulation models, wherein the take-over time corresponding to the numerical reservoir simulation model with the largest recovery ratio is the optimal take-over time. Based on the combination of various chemical flooding methods in the whole offshore oil field development process, the purpose of continuously improving the oil field recovery ratio is achieved, and chemical flooding method screening, chemical flooding method reasonable combination and replacement at the optimal time are formed.

Description

Oil field whole-course chemical flooding combined succession opportunity optimization method and system
Technical Field
The invention relates to a method and a system for optimizing a whole-course chemical flooding combined succession opportunity of an oil field, and belongs to the technical field of oil field exploitation.
Background
Offshore oil fields are mainly enhanced in recovery ratio by well pattern encryption, chemical flooding and other methods. However, offshore oil field development has many limitations such as short platform life, severe development environment, complex geological condition, large investment risk and the like, and generally, a plurality of chemical flooding methods are adopted for combined development in the whole development period of the oil field, so that how to optimize the succession opportunity of different chemical flooding methods is still blank.
Some oil fields in the Bohai sea area have implemented well pattern adjustment and polymer flooding combined measures to further improve the oil field production degree, but the well pattern encryption and polymer flooding combined development sequence, how to take over the combination, which chemical flooding method to take over after the well pattern encryption and polymer flooding are finished and when to take over are all problems which need to be solved urgently in offshore oil field development. At present, partial scholars adopt parameters such as water content and the like as conversion opportunity parameters and calculate the optimal result of chemical flooding conversion opportunity by using an oil reservoir numerical simulation method, but a determination method for chemical flooding method selection and succession opportunity optimization in the whole development process is not provided in the prior art.
Disclosure of Invention
Aiming at the defects of the prior art, the invention aims to provide a method and a system for optimizing the time of whole-course chemical flooding combined succession of an oil field, which are based on the aim of continuously improving the recovery ratio of the oil field by combining and implementing a plurality of chemical flooding methods in the whole process of offshore oil field development, and form methods for screening the chemical flooding methods, reasonably combining the chemical flooding methods and carrying out the succession at the optimal time.
In order to achieve the aim, the invention provides an optimization method for the whole-course chemical flooding combined succession opportunity of an oil field, which comprises the following steps: s1 determining the chemical flooding type and the sequence of the chemical flooding in the whole-course chemical flooding combination; s2 generating oil field parametersWater rate fwAnd dimensionless fluid production index JLDThe relational model of (a); s3, obtaining a reasonable liquid production amount Q under any water content condition according to the production initial condition and the relation model of the oil production well; s4, establishing a plurality of oil reservoir numerical simulation models corresponding to different take-over moments according to the sequence of each chemical flooding in the whole-course chemical flooding combination and the reasonable liquid production amount Q; s5, calculating the recovery ratio of the numerical reservoir simulation models, wherein the take-over time corresponding to the numerical reservoir simulation model with the largest recovery ratio is the optimal take-over time.
Further, the types of chemical flooding in the whole-course chemical flooding combination and the sequence of various chemical flooding are determined according to the permeability, the viscosity of crude oil, the coefficient of variation of permeability and the grade difference of permeability of the oil field.
Further, the determination method of the chemical flooding type and the sequence of various chemical flooding comprises the following steps: when the permeability of the oil field is less than or equal to 390 multiplied by 10-3μm2When the viscosity of the crude oil is less than or equal to 150mPa.s and less than 350mPa.s, the whole chemical flooding combination is water flooding; when the permeability of oil field is more than 390X 10-3μm2When the viscosity of crude oil is more than 50mPa.s and less than 350mPa.s and the difference of permeability is less than 7, the whole chemical flooding combination is encryption water flooding, polymer flooding and binary composite flooding; when the permeability of oil field is more than 390X 10-3μm2When the viscosity of crude oil is more than 50mPa.s and less than 350mPa.s, the coefficient of variation of permeability is less than 0.6, and the difference of permeability is more than 7, the whole-process chemical flooding combination is encryption water flooding, binary composite flooding and gel flooding; when the permeability of oil field is more than 390X 10-3μm2When the viscosity of crude oil is more than 50mPa.s and less than 350mPa.s, the coefficient of variation of permeability is more than 0.6, and the grade difference of permeability is more than 7, the whole chemical flooding combination is the combination of encrypted water flooding, gel flooding and binary combination flooding.
Further, the oilfield parameters include: oil phase relative permeability K of oil fieldroRelative permeability of the aqueous phase KrwCrude oil viscosity μoAnd formation water viscosity muw。
Further, the water content f in step S2wThe calculation formula is as follows:
Figure BDA0002565337090000021
further, the water content f in step S2wAnd dimensionless fluid production index JLDThe relationship model of (a) is:
Figure BDA0002565337090000022
Figure BDA0002565337090000023
Figure BDA0002565337090000024
Figure BDA0002565337090000025
wherein S isorResidual oil saturation; swiIrreducible water saturation; n, a, b and c are undetermined coefficients.
Further, the production initial condition of the oil production well is the production initial time t of the oil production well0Amount of liquid production Q (t)0) And dimensionless fluid production index JLD(t0) Calculating a production pressure difference delta p according to the production initial condition of the oil production well; calculating any water content f according to the relation modelwCorresponding dimensionless fluid production index JLD(ii) a According to dimensionless fluid production index JLDThe product of the pressure difference and the production pressure difference delta p is used for obtaining the water content fwCorresponding reasonable liquid production Q.
Further, the process of establishing a plurality of numerical reservoir simulation models corresponding to different take-over occasions in step S4 is as follows: adopting an oil reservoir numerical simulation method according to different water contents fwEstablishing monthly production dynamic data by reasonable liquid production amount Q under the condition; the oil extraction speed amplitude is used as a quantitative index of the chemical flooding combined method replacing time, a plurality of numerical reservoir simulation models with different replacing times are established, the corresponding recovery ratio of the numerical reservoir simulation models is simulated and calculated, and the numerical reservoir model with the maximum recovery ratioAnd reducing the amplitude of the oil extraction speed corresponding to the simulation model to be the optimal succession time.
Further, the drawdown rate is the ratio of the drawdown rate at the time when a chemical flooding method starts to inject to the highest value of the previous drawdown rate.
The invention also discloses an oil field whole-course chemical flooding combined succession opportunity optimization system, which comprises: the sequence determination module is used for determining the types of chemical flooding in the whole-course chemical flooding combination and the sequence of various chemical flooding; a relational model generation module for generating the water content f according to the oil field parameterswAnd dimensionless fluid production index JLDThe relational model of (a); the liquid production amount calculation module is used for obtaining the reasonable liquid production amount Q under any water content condition according to the initial production condition of the oil production well and the relation model; the numerical simulation model establishing module is used for establishing a plurality of oil reservoir numerical simulation models corresponding to different take-over moments according to the sequence of each chemical flooding in the whole-course chemical flooding combination and the reasonable liquid production amount Q; and the result output model is used for calculating the recovery ratio of the plurality of numerical reservoir simulation models, wherein the take-over time corresponding to the numerical reservoir simulation model with the largest recovery ratio is the optimal take-over time.
Due to the adoption of the technical scheme, the invention has the following advantages:
1. the invention is implemented based on the combination of various chemical flooding methods in the whole offshore oil field development process, and aims to continuously improve the oil field recovery ratio, thereby forming methods of chemical flooding method screening, reasonable combination of chemical flooding methods and succession at the optimal time.
2. When the relay opportunity is optimized, a plurality of simulation models are established by adopting an oil reservoir numerical simulation method, and a method for calculating the optimal liquid production capacity is invented, so that the optimization of the liquid production capacity in the simulation process is considered, and the optimal relay opportunity is determined. The method can be widely applied to the time optimization of the take-over of different chemical flooding methods in the whole process of offshore oilfield chemical flooding development.
Drawings
FIG. 1 is a schematic representation of oil relative permeability and water relative permeability curves for an oil field in an embodiment of the present invention;
FIG. 2 shows a water content f according to an embodiment of the present inventionwAnd dimensionless fluid production index JLDA schematic diagram of the relational model of (a);
fig. 3 is a schematic diagram of a change curve of oil recovery speed corresponding to an optimal succession opportunity in an embodiment of the present invention.
Detailed Description
The present invention is described in detail by way of specific embodiments in order to better understand the technical direction of the present invention for those skilled in the art. It should be understood, however, that the detailed description is provided for a better understanding of the invention only and that they should not be taken as limiting the invention. In describing the present invention, it is to be understood that the terminology used is for the purpose of description only and is not intended to be indicative or implied of relative importance.
Example one
The present embodiment takes an oil field a in a bohai oil field as an example to explain the technical scheme of the present invention.
The embodiment discloses an optimization method for a whole-course chemical flooding combined succession opportunity of an oil field, which comprises the following steps:
s1 identifies the chemical flooding categories and the sequence of the chemical flooding categories in the global chemical flooding pattern.
As shown in figure 1, the types of chemical flooding and the sequence of various chemical flooding in the whole-course chemical flooding combination are determined according to the permeability, the viscosity of crude oil, the variation coefficient of permeability and the grade difference of permeability. The specific method for determining comprises the following steps:
when the permeability of the oil field is less than or equal to 390 multiplied by 10-3μm2When the viscosity of the crude oil is less than or equal to 150mPa.s and less than 350mPa.s, the whole chemical flooding combination is water flooding; when the permeability of oil field is more than 390X 10-3μm2When the viscosity of crude oil is more than 50mPa.s and less than 350mPa.s and the difference of permeability is less than 7, the whole chemical flooding combination is encryption water flooding, polymer flooding and binary composite flooding; when the permeability of oil field is more than 390X 10-3μm2When the viscosity of crude oil is more than 50mPa.s and less than 350mPa.s, the coefficient of variation of permeability is less than 0.6, and the difference of permeability is more than 7, the whole-process chemical flooding combination is encryption water flooding, binary composite flooding and gel flooding; when the permeability of oil field is greater than 390X 10-3μm2When the viscosity of crude oil is less than 350mPa.s and is more than 50mPa.s, the coefficient of variation of permeability is more than 0.6 and the difference of permeability is more than 7, the whole-process chemical flooding combination is the combination of encrypted water flooding, gel flooding and binary flooding.
And (4) according to a certain A oil field in the Bohai sea oil area, calculating four parameters of permeability, crude oil viscosity, permeability variation coefficient and permeability grade difference. Specific values of the four parameters are shown in table 1; according to the screening standard of a chemical flooding combination method, determining that the whole-course chemical flooding combination of the offshore oilfield is the combination of encrypted water flooding, polymer flooding and binary composite flooding.
The encryption water flooding is an oil displacement mode of performing well pattern encryption and then matching with water flooding on the basis of the original well pattern.
TABLE 1 Tablet for taking values of permeability, crude oil viscosity, permeability variation coefficient and permeability grade difference of certain A oil field in Bohai sea oil area
Figure BDA0002565337090000041
S2 generating water content f according to oil field parameterswAnd dimensionless fluid production index JLDThe relationship model of (2) as shown in fig. 2.
Obtaining oilfield parameters from the oil-water relative permeability curve of fig. 1, the oilfield parameters including: oil phase relative permeability K of oil fieldroRelative permeability of the aqueous phase KrwCrude oil viscosity μoAnd formation water viscosity muw。
Water content f in step S2wThe calculation formula is as follows:
Figure BDA0002565337090000042
calculating a plurality of given water cut ratios fwDimensionless fluid production index J under conditionsLDThereby establishing the water content fwAnd dimensionless fluid production index JLDDetermining a dimensionless fluid production index J by a multivariate regression methodLDWith the water content fwThe undetermined coefficient in the relation model has the following specific form:
Figure BDA0002565337090000043
Figure BDA0002565337090000044
Figure BDA0002565337090000051
Figure BDA0002565337090000052
wherein S isorResidual oil saturation; swiIrreducible water saturation; n, a, b and c are undetermined coefficients.
S3, according to the production initial condition and the relation model of the oil production well, the reasonable liquid production amount Q under any water content condition is obtained.
The production initial condition of the oil production well is the production initial time t of the oil production well0Amount of liquid production Q (t)0) And dimensionless fluid production index JLD(t0) Calculating a production pressure difference delta p according to the production initial condition of the oil production well; calculating any water content f according to the relation modelwCorresponding dimensionless fluid production index JLD(ii) a According to dimensionless fluid production index JLDThe product of the pressure difference and the production pressure difference delta p is used for obtaining the water content fwCorresponding reasonable liquid production Q.
Aiming at a certain A oil field in the Bohai sea oil area, the liquid production amount of an oil production well at the initial production time t of 1 day is 120m3D dimensionless fluid production index of J LD1, the calculated production pressure Δ p is 2.2 MPa; dimensionless fluid production index J determined according to multiple regression methodLDWith water content fwA relation model for calculating the arbitrary water content fwDimensionless fluid production index J under conditionsLD(ii) a Dimensionless fluid production index JLDThe product of the pressure difference delta p and the water content fwUnder the condition ofManaging the liquid yield Q.
S4, establishing a plurality of numerical reservoir simulation models corresponding to different take-over moments according to the sequence of each chemical flooding in the whole chemical flooding combination and the reasonable liquid production amount Q.
The process of establishing a plurality of numerical reservoir simulation models corresponding to different take-over occasions in step S4 is as follows: adopting an oil reservoir numerical simulation method according to different water contents fwEstablishing monthly production dynamic data by reasonable liquid production amount Q under the condition; and (3) taking the oil extraction speed reduction amplitude as a quantitative index of the chemical flooding combination method replacing time, establishing a plurality of oil reservoir numerical simulation models with different replacing times, and simulating and calculating the recovery ratio corresponding to the oil reservoir numerical simulation model, wherein the oil extraction speed reduction amplitude corresponding to the oil reservoir numerical simulation model with the largest recovery ratio is the optimal replacing time. The drawdown rate is the ratio of the drawdown rate at the time of the start of injection of a chemical flooding method to the maximum value of the previous drawdown rate. Aiming at the polymer flooding and binary composite flooding methods, in the embodiment, a plurality of numerical reservoir simulation schemes with different successive occasions are established and numerical simulation calculation is carried out when the oil recovery speed reduction amplitude is respectively 100%, 80%, 60% and the like.
S5, calculating the recovery ratio of the numerical reservoir simulation models, wherein the take-over time corresponding to the numerical reservoir simulation model with the largest recovery ratio is the optimal take-over time. The optimal succession time of the polymer flooding is calculated as follows: the oil extraction speed amplitude reduction is 80%, and the optimal succession time of the binary combination flooding is as follows: the amplitude of the oil extraction speed is 60 percent. The oil extraction speed change curve obtained by the whole-course chemical flooding combination succession opportunity optimization scheme of the oil field A is shown in figure 3.
Example two
Based on the same inventive concept, the embodiment discloses an oil field whole-course chemical flooding combined succession opportunity optimization system, which comprises:
the sequence determination module is used for determining the types of chemical flooding in the whole-course chemical flooding combination and the sequence of various chemical flooding;
a relational model generation module for generating the water content f according to the oil field parameterswAnd dimensionless fluid production index JLDThe relationship model of (1);
the liquid production amount calculation module is used for obtaining the reasonable liquid production amount Q under any water content condition according to the initial production condition of the oil production well and the relation model;
the numerical simulation model establishing module is used for establishing a plurality of oil reservoir numerical simulation models corresponding to different take-over moments according to the sequence of each chemical flooding in the whole-course chemical flooding combination and the reasonable liquid production amount Q;
and the result output model is used for calculating the recovery ratio of the plurality of numerical reservoir simulation models, wherein the take-over time corresponding to the numerical reservoir simulation model with the largest recovery ratio is the optimal take-over time.
Finally, it should be noted that: the above embodiments are only for illustrating the technical solutions of the present invention and not for limiting the same, and although the present invention is described in detail with reference to the above embodiments, those of ordinary skill in the art should understand that: modifications and equivalents may be made to the embodiments of the invention without departing from the spirit and scope of the invention, which is to be covered by the claims. The above description is only for the specific embodiments of the present application, but the scope of the present application is not limited thereto, and any person skilled in the art can easily conceive of the changes or substitutions within the technical scope of the present application, and shall be covered by the scope of the present application. Therefore, the protection scope of the present application shall be subject to the protection scope of the claims.

Claims (5)

1. An oil field whole-course chemical flooding combination succession opportunity optimization method is characterized by comprising the following steps:
s1 determining the chemical flooding type and the sequence of the chemical flooding in the whole-course chemical flooding combination;
s2 generating water content f according to oil field parameterswAnd dimensionless fluid production index JLDThe field parameters include: oil phase relative permeability K of oil fieldroRelative permeability of the aqueous phase KrwCrude oil viscosity μoAnd formation water viscosity muw；
The step S2 includesWater rate fwThe calculation formula is as follows:
Figure FDA0003618502220000011
the water content f in the step S2wAnd dimensionless fluid production index JLDThe relationship model of (1) is:
Figure FDA0003618502220000012
Figure FDA0003618502220000013
Figure FDA0003618502220000014
Figure FDA0003618502220000015
wherein S isorResidual oil saturation; swiIrreducible water saturation; n, a, b and c are undetermined coefficients;
s3, obtaining a reasonable liquid production amount Q under any water content condition according to the production initial condition of the oil production well and the relation model;
the production initial condition of the oil production well is the production initial time t of the oil production well0Amount of liquid production Q (t)0) And dimensionless fluid production index JLD(t0) Calculating a production pressure difference delta p according to the production initial condition of the oil production well; calculating any water content f according to the relation modelwCorresponding dimensionless fluid production index JLD(ii) a According to the dimensionless fluid collection index JLDThe product of the pressure difference delta p and the water content f is obtainedwThe corresponding reasonable liquid production amount Q;
s4, establishing a plurality of oil reservoir numerical simulation models corresponding to different take-over moments according to the sequence of each chemical flooding in the whole-process chemical flooding combination and the reasonable liquid production amount Q;
the process of establishing a plurality of numerical reservoir simulation models corresponding to different succession occasions comprises the following steps: adopting an oil reservoir numerical simulation method according to different water contents fwEstablishing monthly production dynamic data by the reasonable liquid production amount Q under the condition; taking the oil extraction speed reduction amplitude as a quantitative index of the chemical flooding combined method replacing time, establishing a plurality of oil reservoir numerical simulation models with different replacing times, and simulating and calculating the recovery ratio corresponding to the oil reservoir numerical simulation model, wherein the oil extraction speed reduction amplitude corresponding to the oil reservoir numerical simulation model with the largest recovery ratio is the optimal replacing time;
s5, calculating the recovery ratio of the numerical reservoir simulation models, wherein the take-over time corresponding to the numerical reservoir simulation model with the maximum recovery ratio is the optimal take-over time.
2. The method of optimizing a succession opportunity for a full range chemical flooding combination in an oil field of claim 1, wherein the type of chemical flooding and the order of the various chemical flooding in the full range chemical flooding combination are determined according to the permeability, the viscosity of the crude oil, the coefficient of permeability variation, and the permeability level difference of the oil field.
3. The method for optimizing the time for the whole-course chemical flooding combined succession of the oilfield according to claim 2, wherein the method for determining the types of the chemical flooding and the sequence of the various chemical flooding comprises the following steps:
when the permeability of the oil field is less than or equal to 390 multiplied by 10-3μm2When the viscosity of the crude oil is less than or equal to 150mPa.s and less than 350mPa.s, the whole chemical flooding combination is water flooding;
when the permeability of oil field is more than 390X 10-3μm2When the viscosity of crude oil is more than 50mPa.s and less than 350mPa.s and the permeability grade difference is less than 7, the whole chemical flooding combination is encryption water flooding, polymer flooding and binary composite flooding;
when the permeability of oil field is greater than 390X 10-3μm2Crude oil viscosity is less than 350mPa.s and is less than 50mPa.s, permeability coefficient of variation is less than 0.6, and permeability grade differenceWhen the total chemical flooding is more than 7, the whole chemical flooding combination is encryption water flooding, binary composite flooding and gel flooding;
when the permeability of oil field is more than 390X 10-3μm2When the viscosity of crude oil is less than 350mPa.s and is more than 50mPa.s, the coefficient of variation of permeability is more than 0.6 and the difference of permeability is more than 7, the whole-process chemical flooding combination is the combination of encrypted water flooding, gel flooding and binary flooding.
4. The method for optimizing the timing of a global chemical flooding combined take-over in an oilfield of claim 1, wherein the drawdown rate is a ratio of a drawdown rate at a time when a chemical flooding process begins to inject to a highest value of a previous drawdown rate.
5. The utility model provides an oil field whole journey chemical flooding combination timing of taking over optimizing system which characterized in that includes:
the sequence determination module is used for determining the types of chemical flooding in the whole-course chemical flooding combination and the sequence of various chemical flooding;
a relational model generation module for generating the water content f according to the oil field parameterswAnd dimensionless fluid production index JLDThe field parameters include: oil phase relative permeability K of oil fieldroRelative permeability of the aqueous phase KrwCrude oil viscosity μoAnd formation water viscosity muw；
The water content f in the step S2wThe calculation formula is as follows:
Figure FDA0003618502220000021
the water content f in the step S2wAnd dimensionless fluid production index JLDThe relationship model of (1) is:
Figure FDA0003618502220000022
Figure FDA0003618502220000023
Figure FDA0003618502220000031
Figure FDA0003618502220000032
wherein S isorResidual oil saturation; swiIrreducible water saturation; n, a, b and c are undetermined coefficients;
the liquid production amount calculation module is used for obtaining the reasonable liquid production amount Q under any water content condition according to the initial production condition of the oil production well and the relation model, wherein the initial production condition of the oil production well is the initial production time t of the oil production well0Amount of liquid production Q (t)0) And dimensionless fluid production index JLD(t0) Calculating a production pressure difference delta p according to the production initial condition of the oil production well; calculating any water content f according to the relation modelwCorresponding dimensionless fluid production index JLD(ii) a According to the dimensionless fluid collection index JLDThe product of the pressure difference delta p and the water content f is obtainedwThe corresponding reasonable liquid production amount Q;
the numerical simulation model establishing module is used for establishing a plurality of oil reservoir numerical simulation models corresponding to different take-over moments according to the sequence of each chemical flooding in the whole-process chemical flooding combination and the reasonable liquid production amount Q; the process of establishing a plurality of numerical reservoir simulation models corresponding to different succession occasions comprises the following steps: adopting an oil reservoir numerical simulation method according to different water contents fwEstablishing monthly production dynamic data by the reasonable liquid production amount Q under the condition; taking the oil extraction speed reduction amplitude as a quantitative index of the chemical flooding combined method replacing time, establishing a plurality of oil reservoir numerical simulation models with different replacing times, and simulating and calculating the recovery ratio corresponding to the oil reservoir numerical simulation model, wherein the oil extraction speed reduction amplitude corresponding to the oil reservoir numerical simulation model with the largest recovery ratio is the optimal replacing time;
and the result output model is used for calculating the recovery ratio of the plurality of numerical reservoir simulation models, wherein the take-over time corresponding to the numerical reservoir simulation model with the maximum recovery ratio is the optimal take-over time.
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