CN113674100B

CN113674100B - Oil reservoir injection and production optimization method and device, storage medium and electronic equipment

Info

Publication number: CN113674100B
Application number: CN202010408280.5A
Authority: CN
Inventors: 杨森; 孙建芳; 龚蔚青
Original assignee: China Petroleum and Chemical Corp; Sinopec Exploration and Production Research Institute
Current assignee: China Petroleum and Chemical Corp; Sinopec Exploration and Production Research Institute
Priority date: 2020-05-14
Filing date: 2020-05-14
Publication date: 2024-04-30
Anticipated expiration: 2040-05-14
Also published as: CN113674100A

Abstract

The application relates to the technical field of oil reservoir numerical simulation application and oil reservoir recovery ratio improvement, in particular to an oil reservoir injection and production optimization method, an oil reservoir injection and production optimization device, a storage medium and electronic equipment, which solve the problem that the oil reservoir recovery ratio cannot be accurately evaluated under the influence of the characteristics of a temperature-sensitive compound profile control system in the prior art. According to the method, a relation model of aqueous phase viscosity and temperature change of temperature-sensitive plugging agent component concentration and temperature change is used for representing a change rule of viscosity after the temperature-sensitive plugging agent component exists in each grid block, a chemical relation model of water-soluble viscosity reducer component in the aqueous phase and original components in the oil phase is used for representing a chemical viscosity reduction process, a change rule of a permeability curve is corrected by an oil phase relative permeability curve along with the change relation model of an improved capillary number, dynamic changes of reservoir physical properties and fluid rheological parameters calculated by each iteration of each grid are updated, and oil reservoir injection and production are optimized according to the obtained second aqueous phase relative permeability and second oil phase relative permeability.

Description

Oil reservoir injection and production optimization method and device, storage medium and electronic equipment

Technical Field

The application relates to the technical field of oil reservoir numerical simulation application and oil reservoir injection and production optimization, in particular to an oil reservoir injection and production optimization method, an oil reservoir injection and production optimization device, a storage medium and electronic equipment.

Background

The current oil reservoir numerical simulation technology is the most important means for evaluating the effect of a certain oil field development mode. However, the numerical simulation software of the oil reservoir developed at home and abroad generally only comprises mature chemical flooding numerical simulation methods aiming at polymer flooding, surfactant flooding, ASP ternary complex flooding and the like, the methods generally assume that the oil reservoir is in a constant temperature state (oil reservoir temperature) or the influence of temperature change on the chemical flooding effect is negligible in a certain range in the chemical flooding process, and the indoor experimental research shows that the oil displacement technology based on the temperature-sensitive complex flooding system can obviously expand the sweep and greatly improve the oil reservoir recovery ratio.

However, in the related art, the rheological property change of the displaced phase (plugging agent) caused by temperature, the rheological property change of the displaced phase (crude oil) caused by the physicochemical action of the chemical agent cannot be reasonably represented, and when the displaced phase is a temperature-sensitive compound flooding system, the displacement effect change has larger errors in the oil displacement effect, the residual macroscopic distribution and the potential evaluation of the pre-temperature-sensitive compound flooding system. The temperature-sensitive composite profile control system can change the concentration and viscosity of the temperature-sensitive profile control agent in the oil reservoir, so that the accumulated oil yield and the recovery ratio of the oil reservoir are changed, and the oil reservoir injection and production optimization is not realized under the influence of the characteristics of the temperature-sensitive composite profile control system in the prior art.

Disclosure of Invention

Aiming at the problems, the application provides an oil reservoir injection and production optimization method, an oil reservoir injection and production optimization device, a storage medium and electronic equipment, and solves the technical problem that oil reservoir injection and production optimization is not realized under the influence of the characteristics of a temperature-sensitive compound profile control system in the related art.

In a first aspect, the present application provides a method for optimizing oil reservoir injection and production, the method comprising:

Step S110: establishing an oil reservoir exploitation model based on oil reservoir parameters, and acquiring an initial data field of each grid block in the oil reservoir exploitation model, wherein the data fields comprise a saturation data field, a pressure data field, a temperature data field, a viscosity data field and a relative permeability data field;

Step S120: acquiring accumulated flow of each grid block in the oil reservoir exploitation model, and acquiring a first saturation data field, a first temperature data field and a first pressure data field in each grid block according to the accumulated flow;

step S130: obtaining a first viscosity data field of the aqueous phase in each grid block according to a relation model of the aqueous phase viscosity and the temperature change of the temperature-sensitive plugging agent component concentration and the temperature change;

Step S140: obtaining an oil phase second viscosity data field, an oil phase second saturation data field, an aqueous phase second viscosity data field and an aqueous phase second saturation data field in each grid block according to a chemical reaction relation model of a viscosity reducer component in the aqueous phase and a crude oil component in the oil phase;

Step S150: acquiring a first water phase relative permeability data field in each grid block according to a relation model of the adsorption quantity of a temperature-sensitive plugging agent component in the water phase in unit pore volume and the change of the water phase relative permeability;

Step S160, obtaining a first oil phase relative permeability data field according to a relation model of the oil phase relative permeability data field along with the change of the capillary number;

Step S170: obtaining updated data fields according to the first saturation data field, the first temperature data field, the first pressure data field, the water phase first viscosity data field, the oil phase second saturation data field, the water phase second viscosity data field, the water phase second saturation data field, the first water phase relative permeability data field and the first oil phase relative permeability data field;

step S180: replacing the initial data field in the step S120 with the updated data field, and circularly executing the steps S120-S170 within preset time to obtain a second water phase relative permeability and a second oil phase relative permeability;

step S190: and optimizing oil reservoir injection and production based on the second water phase relative permeability and the second oil phase relative permeability.

According to an embodiment of the present application, optionally, in the above method for optimizing oil reservoir injection and production, the establishing an oil reservoir production model based on oil reservoir parameters includes establishing based on the following calculation formula:

Wherein F _i represents a convection term, A _i represents an accumulation phase, B _i represents a yield term, t represents time, and the value range of i is 3-4.

According to an embodiment of the present application, optionally, in the method for optimizing oil reservoir injection and production, step S110: establishing an oil deposit exploitation model based on oil deposit parameters, and acquiring an initial data field of each grid block in the oil deposit exploitation model, wherein the initial data field comprises the following steps: and acquiring a data field of all components of each phase of each grid block in the oil reservoir exploitation model.

According to an embodiment of the present application, optionally, in the method for optimizing oil reservoir injection and production, step S120: acquiring the accumulated flow of each grid block in the oil reservoir exploitation model, and acquiring a first saturation data field, a first temperature data field and a first pressure data field in each grid block according to the accumulated flow, wherein the method comprises the following steps:

respectively acquiring the flow of all components of each phase in each direction of each grid block according to the pressure data field, and respectively acquiring the accumulated flow of each phase in all directions of each grid block according to the flow;

Respectively acquiring a first saturation data field, a first temperature data field and a first pressure data field of each phase in all directions of each grid block according to the accumulated flow and the state equation of each phase in all directions of each grid block;

wherein the accumulated flow comprises the total mass of fluid per phase per time step through each grid block X, Y, Z and the mass of all components of each grid block.

According to an embodiment of the present application, optionally, in the method for optimizing oil reservoir injection and production, step S130: obtaining a first viscosity data field of the water phase in each grid block according to a relation model of the viscosity of the water phase and the concentration and temperature change of the temperature-sensitive plugging agent component, wherein the first viscosity data field comprises:

According to the temperature-sensitive plugging agent component viscosity and the water phase component viscosity after the temperature-sensitive plugging agent is added into each grid block, a first viscosity field of the water phase in each grid block is obtained based on the following calculation:

wherein mu _aq represents the water phase mixing viscosity, W _p represents the molar concentration of the polymer, mu _w represents the viscosity of the water phase, M represents the mass of liquid in the oil reservoir, mu _p (C, T) represents the viscosity of the temperature-sensitive plugging agent, n _c represents the component fraction of the water phase, S is a preset range, the value range of i is 3-4,w _i represents the molar fraction of the i component of the j phase, and mu _i represents the viscosity of the i component of the water phase.

According to an embodiment of the present application, optionally, in the method for optimizing oil reservoir injection and production, step S140: obtaining an oil phase second viscosity data field, an oil phase second saturation data field, an aqueous phase second viscosity data field and an aqueous phase second saturation data field in each grid block according to a chemical reaction relation model of a viscosity reducer component in the aqueous phase and a crude oil component in the oil phase, wherein the method comprises the following steps:

And obtaining an oil phase second viscosity data field, an oil phase second saturation data field, an aqueous phase second viscosity data field and an aqueous phase second saturation data field in each grid block according to a chemical reaction formula of the viscosity reducer component in the aqueous phase and the crude oil component in the oil phase in a chemical reaction process.

According to an embodiment of the present application, optionally, in the method for optimizing oil reservoir injection and production, step S150: acquiring a first water phase relative permeability data field in each grid block according to a relation model of adsorption quantity of a temperature-sensitive plugging agent component in a unit pore volume and water phase relative permeability change, wherein the first water phase relative permeability data field comprises the following components:

according to the adsorption quantity of the temperature-sensitive plugging agent component in the unit pore volume and the relative permeability of the water phase in each grid water phase, acquiring a first relative permeability data field of the water phase in each grid block based on the following calculation formula:

Where k _w represents the effective permeability of the aqueous phase after plugging, k _rw represents the phase permeability of the aqueous phase, k _abs represents the absolute permeability of the rock, and R _kw represents the water phase permeability reduction factor.

In a second aspect, the present application provides an oil reservoir injection and production optimization device, the device comprising:

A model building module configured to build an oil reservoir production model based on oil reservoir parameters, obtain an initial data field for each of the grid blocks in the oil reservoir production model, wherein the data fields include a saturation data field, a pressure data field, a temperature data field, a viscosity data field, and a relative permeability data field;

the first data acquisition module is configured to acquire accumulated flow of each grid block in the oil reservoir exploitation model, and acquire a first saturation data field, a first temperature data field and a first pressure data field in each grid block according to the accumulated flow;

The second data acquisition module is configured to acquire a first viscosity data field of the aqueous phase in each grid block according to a relation model of the viscosity of the aqueous phase and the concentration and temperature change of the temperature-sensitive plugging agent component;

the third data acquisition module is configured to acquire an oil phase second viscosity data field, an oil phase second saturation data field, an aqueous phase second viscosity data field and an aqueous phase second saturation data field in each grid block according to a chemical reaction relation model of the viscosity reducer component in the aqueous phase and the crude oil component in the oil phase;

the fourth data acquisition module is configured to acquire a first water phase relative permeability data field in each grid block according to a relation model of the adsorption quantity of the temperature-sensitive plugging agent component in the water phase in unit pore volume and the change of the water phase relative permeability;

the fifth data acquisition module is configured to acquire a first oil phase relative permeability data field according to a relation model of the oil phase relative permeability data field along with the change of the capillary number;

A sixth data acquisition module configured to obtain updated data fields from the first saturation data field, first temperature data field, and first pressure data field, the aqueous phase first viscosity data field, the oil phase second viscosity data field, an oil phase second saturation data field, an aqueous phase second viscosity data field, and aqueous phase second saturation data field, a first aqueous phase relative permeability data field, a first oil phase relative permeability data field;

The control module is configured to control the oil reservoir exploitation model to perform iterative computation within a preset time according to the updated data field to replace the initial data field in the oil reservoir exploitation model, so as to obtain a second water phase relative permeability and a second oil phase relative permeability;

An optimization module configured to optimize reservoir injection and production based on the second aqueous phase relative permeability and second oil phase relative permeability.

According to an embodiment of the present application, optionally, in the above oil reservoir injection and production optimization device, the establishing an oil reservoir production model based on oil reservoir parameters includes establishing based on the following calculation formula:

According to an embodiment of the present application, optionally, in the oil reservoir injection and production optimization device, step S110: establishing an oil deposit exploitation model based on oil deposit parameters, and acquiring an initial data field of each grid block in the oil deposit exploitation model, wherein the initial data field comprises the following steps: and acquiring a data field of all components of each phase of each grid block in the oil reservoir exploitation model.

According to an embodiment of the present application, optionally, in the oil reservoir injection and production optimization device, step S120: acquiring the accumulated flow of each grid block in the oil reservoir exploitation model, and acquiring a first saturation data field, a first temperature data field and a first pressure data field in each grid block according to the accumulated flow, wherein the method comprises the following steps:

According to an embodiment of the present application, optionally, in the oil reservoir injection and production optimization device, step S130: obtaining a first viscosity data field of the water phase in each grid block according to a relation model of the viscosity of the water phase and the concentration and temperature change of the temperature-sensitive plugging agent component, wherein the first viscosity data field comprises:

wherein mu _aq represents the water phase mixing viscosity, W _p represents the molar concentration of the polymer, mu _w represents the viscosity of the water phase, M represents the mass of liquid in the oil reservoir, mu _p (C, T) represents the viscosity of the temperature-sensitive plugging agent, n _c represents the component fraction of the water phase, S is a preset range, the value range of i is 3-4,w _i represents the molar fraction of the component i of the water phase, and mu _i represents the viscosity of the component i of the water phase.

According to an embodiment of the present application, optionally, in the oil reservoir injection and production optimization device, step S140: obtaining an oil phase second viscosity data field, an oil phase second saturation data field, an aqueous phase second viscosity data field and an aqueous phase second saturation data field in each grid block according to a chemical reaction relation model of a viscosity reducer component in the aqueous phase and a crude oil component in the oil phase, wherein the method comprises the following steps:

According to an embodiment of the present application, optionally, in the oil reservoir injection and production optimization device, step S150: obtaining a first water phase relative permeability data field of the water phase in each grid block according to a relation model of the adsorption quantity of the temperature-sensitive plugging agent component in the water phase in unit pore volume and the change of the relative permeability of the water phase, wherein the data field comprises the following components:

In a third aspect, the present application provides a storage medium storing a computer program executable by one or more processors for implementing a reservoir injection and production optimization method as described above.

In a fourth aspect, the present application provides an electronic device, including a memory and a processor, where the memory stores a computer program, and the memory and the processor are communicatively connected to each other, and when the computer program is executed by the processor, the method for optimizing oil reservoir injection and production is executed.

Compared with the prior art, the oil reservoir injection and production optimization method, the storage medium and the electronic equipment provided by the application have the beneficial effects that:

The change rule of the viscosity after the temperature-sensitive plugging agent component exists in each grid block is represented by a relation model of the water phase viscosity and the temperature change of the temperature-sensitive plugging agent component, the chemical relation model of the water-soluble viscosity reducer component in the water phase and the original component in the oil phase represents the chemical viscosity reduction process, the change rule of the permeability curve is corrected by the relation model of the change of the oil phase relative permeability curve along with the improvement of the capillary number, the data field in each grid is updated in the iterative calculation process of the oil reservoir exploitation model, the oil reservoir injection and exploitation scheme is optimized under the influence of the characteristic of the sensitive composite profile control and flooding system, the accuracy of the numerical simulation prediction result of the water-soluble viscosity reducer chemical viscosity reduction and oil displacement effect is improved, the stability and the reliability of the oil reservoir exploitation model simulation result are ensured, and powerful support is provided for reasonably optimizing the technical policy of oil field exploitation, accurately evaluating the oil reservoir to improve the recovery ratio potential and effectively formulating the oil field exploitation scheme.

Drawings

The application will be described in more detail hereinafter on the basis of embodiments and with reference to the accompanying drawings:

FIG. 1 is a schematic flow chart of an oil reservoir injection and production optimization method provided by an embodiment of the application;

FIG. 2 is a schematic diagram of the relationship between the concentration of the temperature-sensitive viscoelastic polymer plugging agent component and the temperature change provided by the embodiment of the application;

FIG. 3 is a schematic diagram showing the relationship between the adsorption amount of the temperature-sensitive viscoelastic polymer plugging agent component per unit pore volume and the relative permeability of water phase;

FIG. 4 is a schematic diagram of the relationship between the number of improved capillary and the value of the end point of the infiltration according to the embodiment of the present application;

FIG. 5 is a comparison chart of recovery ratio without considering characteristics of a temperature-sensitive compound profile control system and with considering characteristics of the temperature-sensitive compound profile control system according to an embodiment of the present application;

fig. 6 is a connection block diagram of an oil reservoir injection and production optimizing device provided by an embodiment of the application.

In the drawings, like parts are given like reference numerals, and the drawings are not drawn to scale.

Detailed Description

The following will describe embodiments of the present application in detail with reference to the drawings and examples, thereby solving the technical problems by applying technical means to the present application, and realizing the corresponding technical effects can be fully understood and implemented accordingly. The embodiment of the application and the characteristics in the embodiment can be mutually combined on the premise of no conflict, and the formed technical scheme is within the protection scope of the application.

The method characterizes a change rule of viscosity after temperature-sensitive plugging agent components exist in each grid block through a relation model of aqueous phase viscosity and temperature-sensitive plugging agent component concentration and temperature change, a chemical relation model of water-soluble viscosity reducer components in aqueous phase and original components in oil phase characterizes a chemical viscosity reduction process, a change rule of an oil phase relative permeability curve is corrected along with a change relation model of improved capillary number, dynamic changes of reservoir physical properties and fluid rheological parameters calculated by each iteration of each grid are updated, quick, continuous and accurate simulation calculation based on characteristics of a temperature-sensitive composite plugging agent and flooding system can be realized, and stability and reliability of a simulation result of an oil reservoir exploitation model are ensured.

Example 1

Fig. 1 is a schematic flow chart of an oil reservoir injection and production optimization method provided by an embodiment of the present application, where, as shown in fig. 1, the method includes:

step S150: acquiring a first water phase relative permeability data field in each grid block according to a relation model of adsorption quantity of a unit pore volume of a temperature-sensitive plugging agent component in the water phase and water phase relative permeability change;

Specifically, according to the first saturation data field, the first temperature data field, the first pressure data field, the water phase first viscosity data field, the oil phase second saturation data field, the water phase second viscosity data field, the water phase second saturation data field, the first water phase relative permeability data field and the first oil phase relative permeability data field, an updated data field is obtained through a finite difference method.

The method for obtaining the updated data field by the finite difference method is a technical means well known to those skilled in the art, and the present application is not described in detail herein.

In this embodiment, the preset time is 10 years.

The order of steps S130 to S150 may be adjusted.

Further, establishing the reservoir recovery model based on the reservoir parameters includes establishing based on the following calculations:

Where i is a group score, i=1, 2,..;

F _i is a convection term;

a _i is the cumulative term;

B _i is yield term.

Specific:

Convection item

Wherein Y _ij is the phase concentration, representing the concentration of component i in phase j;

ρ _j represents the j-phase concentration, phase number j=1, 2,..;

V _j represents the Darcy speed in m ³/d.

Specifically, the expression of darcy's velocity is as follows:

wherein p _j represents j phases of pressure, the number of phases j=1, 2.

K represents the absolute permeability of the rock, and the unit is mD;

K _rj represents the relative permeability of the j phase, which is a decimal;

lambda _j represents the flow correction coefficient of the j-phase flow, and the unit is mPa.s;

y _ij is the phase concentration, indicating the concentration of component i in phase j.

In particular, the method comprises the steps of,

Yield item B _i＝Q_i+R_i (4)

Wherein Q _i represents the injection/output of the i component;

r _i represents an increase or decrease in mass of the i component due to a chemical reaction or the like.

Further, step S110: establishing an oil deposit exploitation model based on oil deposit parameters, and acquiring an initial data field of each grid block in the oil deposit exploitation model, wherein the initial data field comprises the following steps: and acquiring a data field of all components of each phase of each grid block in the oil reservoir exploitation model.

Wherein each phase comprises an aqueous phase, an oil phase, and a gas phase when a gas reservoir exists; all components include all components included in the reservoir, such as water components, oil components, polymer components (emulsion components) after adding the temperature sensitive plugging agent, and the like in the reservoir.

Further, step S120: acquiring the accumulated flow of each grid block in the oil reservoir exploitation model, and acquiring a first saturation data field, a first temperature data field and a first pressure data field in each grid block according to the accumulated flow, wherein the method comprises the following steps:

Wherein the equation of state refers to an equation describing the relationship between fluid density and temperature and pressure.

The state equation includes: ρ=ρ ₀[1+C_L(P-P₀) ] (5

Wherein ρ represents the current density;

ρ ₀ represents the initial density;

C _L represents an elastic compression coefficient;

P current pressure;

p ₀ represents the initial pressure.

Further, step S130: obtaining a first viscosity data field of the water phase in each grid block according to a relation model of the viscosity of the water phase and the concentration and temperature change of the temperature-sensitive plugging agent component, wherein the first viscosity data field comprises:

Wherein μ _aq represents the aqueous phase mixing viscosity;

Mu _p (C, T) represents the viscosity of the temperature-sensitive plugging agent;

Mu _i represents the viscosity of the aqueous phase i component;

w _p represents the molar concentration of the polymer;

w _i represents the mole fraction of the i component of the aqueous phase;

n _c represents the component fraction of the aqueous phase;

S is a preset range;

The value range of i is 3-4.

In particular, the method comprises the steps of,

Wherein μ _aq represents the aqueous phase mixing viscosity;

Mu _i represents the viscosity of the aqueous phase i component;

w _p represents the molar component concentration of the polymer;

w _i represents the mole fraction of the i component of the aqueous phase;

M represents the mass of liquid in the reservoir, and mu _w represents the viscosity of the aqueous phase;

The value range of i is 3-4.

Wherein the temperature-sensitive plugging agent comprises a temperature-sensitive polymer plugging agent.

Further, step S140: obtaining an oil phase second viscosity data field, an oil phase second saturation data field, an aqueous phase second viscosity data field and an aqueous phase second saturation data field in each grid block according to a chemical reaction relation model of a viscosity reducer component in the aqueous phase and a crude oil component in the oil phase, wherein the method comprises the following steps:

Wherein, the chemical reaction formula in the chemical reaction process of the viscosity reducer component in the water phase and the original component in the oil phase comprises:

Wherein oil is crude oil, A is the proportion of crude oil in the chemical reaction formula, reducer is viscosity reducer, B is the proportion of viscosity reducer in the chemical reaction formula, emulsion is Emulsion, and C is the proportion of Emulsion in the chemical reaction formula.

Further, the step S150: acquiring a first water phase relative permeability data field in each grid block according to a relation model of adsorption quantity of unit pore volume of a temperature-sensitive plugging agent component in the water phase and water phase relative permeability change, wherein the method comprises the following steps:

According to the adsorption quantity of the temperature-sensitive plugging agent component in the unit pore volume and the relative permeability of the water phase in each grid water phase, acquiring a data field of the relative permeability of the water phase in the first water phase in each grid block based on the following calculation formula:

wherein k _w represents the effective permeability of the aqueous phase after plugging, mD;

k _rw is the water phase permeability;

k _abs represents the absolute permeability of the rock;

R _kw represents the water phase permeability reduction factor.

Wherein,

Wherein R _kw represents an aqueous phase permeability reduction factor;

RRF _w represents the aqueous phase residual resistance factor;

Ad _cell represents the adsorption quantity and mol of the plugging agent in the unit volume grid;

ADMAXT represents the maximum adsorption amount and mol of the plugging agent in the unit volume grid.

The relative permeability is an important physical parameter of the oil reservoir, and the accuracy of the value is of great practical significance for reliably predicting the behavior of the oil reservoir.

Further, step S190: optimizing oil reservoir injection and production based on the second aqueous phase relative permeability and second oil phase relative permeability, comprising: and obtaining the recovery ratio and the accumulated oil yield of the oil field under different concentrations and dosages of the temperature-sensitive plugging agent according to the relative permeability of the second water phase and the relative permeability of the second oil phase, and comparing the magnitude of the recovery ratio and the accumulated oil yield under different conditions, thereby determining an optimal oil reservoir injection and production scheme and realizing the oil reservoir injection and production optimization.

The yield of each small layer of the oil field and the dynamic analysis of water displacement can be estimated according to the relative permeability, and the fitting degree of the estimation result and the physical experiment result reaches more than 90%.

Specifically, in the preset time, the oil reservoir exploitation model can obtain new relative water phase permeability and oil phase relative permeability in each iterative calculation process, different relative water phase permeability and oil phase relative permeability can show different concentrations and different dosages of the temperature-sensitive plugging agent, and the accumulated oil yield and the recovery ratio of the oil reservoir are also different under different concentrations and different dosages of the temperature-sensitive plugging agent. When the accumulated oil yield of the oil deposit is low and/or the recovery ratio is low, the accumulated oil yield and/or the recovery ratio of the oil deposit can be changed by adjusting the concentration and the dosage of the temperature-sensitive plugging agent to obtain an oil deposit injection and production scheme, so that the oil deposit injection and production optimization is realized.

The embodiment provides an oil reservoir injection and production optimization method, which comprises the following steps: establishing an oil reservoir exploitation model based on oil reservoir parameters, representing the change rule of viscosity after temperature-sensitive plugging agent components exist in each grid block through a relation model of water phase viscosity and temperature-sensitive plugging agent component concentration and temperature change, representing a chemical viscosity reduction process through a chemical relation model of water-soluble viscosity reducer components in the water phase and original components in the oil phase, correcting the change rule of a permeability curve through an oil phase relative permeability curve along with the change relation model of improved capillary number, and updating a data field in each grid in the iterative calculation process of the oil reservoir exploitation model to obtain the oil reservoir exploitation model based on the characteristics of a sensitive composite profile control and flooding system; for the water-soluble viscosity reducer and the oil displacement effect, the simulation prediction result of the oil reservoir exploitation model meets the requirement of industrial application precision; and the simulation result of the oil reservoir exploitation simulation model reasonably evaluates the synergistic effect of the temperature-sensitive compound profile control system, ensures the better and reliable oil reservoir injection and exploitation, and provides powerful support for reasonably optimizing the technical policy of oil field exploitation, accurately evaluating the potential of oil reservoir for improving the recovery ratio and effectively formulating the oil field exploitation scheme.

Example two

In an oil reservoir, a temperature-sensitive composite profile control and flooding system is designed and constructed according to the heterogeneous characteristics of the oil reservoir and the distribution rule of residual oil, and is a composite oil displacement system which is formed by combining a temperature-sensitive viscoelastic polymer profile control agent and a water-soluble viscosity reducer in a slug way according to a certain proportion and has the functions of medium-deep profile control and emulsification viscosity reduction oil displacement. A large amount of indoor experimental research data show that the oil displacement technology based on the temperature-sensitive compound profile control system can obviously expand the sweep and greatly improve the oil reservoir recovery ratio.

The temperature-sensitive viscoelastic polymer plugging agent is a multipolymer with temperature-sensitive property prepared by a free radical aqueous solution polymerization method on the basis of selecting a proper comonomer. The main characteristic of the temperature-sensitive viscous polymer plugging agent is that the viscosity of the plugging agent solution system is greatly changed at a certain temperature or within a certain temperature range according to the geological conditions and development characteristics of a target oil reservoir, for example, when the temperature rises above a certain critical value and gradually rises within a certain range, the viscosity of the plugging agent solution system is suddenly increased. The characteristics of the temperature-sensitive viscoelastic polymer plugging agent in the porous medium are that when the temperature-sensitive viscoelastic polymer plugging agent solution just enters a reservoir, the temperature of the temperature-sensitive viscoelastic polymer plugging agent solution is lower, the viscosity is low, the flowing capability is stronger, and the temperature-sensitive viscoelastic polymer plugging agent solution enters a high-water-content and high-permeability porous medium of the reservoir along with injected water; in the process of moving to the deep part of the reservoir, under the action of stratum heating, the temperature of the solution is gradually increased, when the critical temperature is reached, the viscosity of the solution is suddenly increased, and a high-water-content and high-permeability channeling channel is blocked, so that the subsequent injection fluid is diverted to bypass; thus realizing pressure bearing and shearing reduction in near well zones and plugging adjustment and sweep expansion in far well zones.

Therefore, when the influence of the temperature-sensitive compound profile control system on the oil reservoir simulation result is considered, the change of the data field of each component of each grid block in the oil reservoir exploitation model is considered in the working process of the oil reservoir exploitation model under the influence of the temperature-sensitive compound profile control system.

In this embodiment, the law of change of viscosity after the temperature-sensitive viscoelastic plugging agent component exists in each grid block is represented by a relation model of aqueous phase viscosity and temperature-sensitive plugging agent component concentration and temperature change.

For example, fig. 2 is a schematic diagram showing a relationship between a component concentration and a temperature change of a temperature-sensitive viscoelastic polymer plugging agent provided in the embodiment of the application, and as shown in fig. 2, when the concentration of the temperature-sensitive viscoelastic polymer plugging agent is 1500ppm and is greater than the aqueous phase viscosity when the concentration is 3000ppm in a temperature state of the same 40 ℃, when the temperature rises above a certain critical value and gradually rises in a certain interval, the viscosity of a temperature-sensitive viscoelastic polymer plugging agent solution system is suddenly increased, and the viscosity in the fluid is affected after the fluid is injected.

Fig. 3 is a schematic diagram of a relationship between adsorption capacity of a unit pore volume of a temperature-sensitive viscoelastic polymer plugging agent component and relative permeability of an aqueous phase, as shown in fig. 3, in which adsorption capacity of the unit pore volume of the temperature-sensitive viscoelastic polymer plugging agent component is proportional to relative permeability of the aqueous phase, and in a process of continuously increasing adsorption capacity of the unit pore volume of the temperature-sensitive viscoelastic polymer plugging agent component, relative permeability of the aqueous phase is increased, and after the temperature-sensitive viscoelastic polymer plugging agent is injected into a fluid, relative permeability of the aqueous phase in the fluid is also affected.

Under the same condition, the oil displacement efficiency of the temperature-sensitive compound oil displacement system is higher than that of a single agent and the sum of the oil displacement efficiencies of the single agents, so that the synergistic effect is also one of the main characteristics of the temperature-sensitive compound oil displacement system.

The synergistic characteristics of chemical compound oil displacement systems such as general SP (Surfactant-Polymer Flooding), ASP (Alkali-Surfactant-Polymer Flooding), and the like are described by an infiltration curve difference value calculation method based on a capillary number model.

However, in recent years, researches of domestic and foreign scholars find that when the property of crude oil and an oil displacement system are changed, the traditional capillary number model is not suitable for describing the relationship between the permeability endpoint value and the temperature-sensitive compound profile control system parameter under the condition, and the synergistic interaction between chemical agents is ignored, so that the traditional capillary number model and the recovery ratio are not necessarily well correlated.

Fig. 4 is a schematic diagram showing a relationship between the number of improved tubes and the permeability endpoint according to an embodiment of the present application, as shown in fig. 4, in the same number of improved tubes 1E-07, the permeability endpoint corresponding to the saturation level of the residual oil is greater than the permeability endpoint corresponding to the permeability of the water phase under the saturation level of the residual oil, and at this time, the permeability endpoint needs to be corrected.

The main viscosity reduction and oil displacement mechanism of the water-soluble viscosity reducer molecule is that chemical reaction is carried out between the main hydrophobic structure and the functions carried by heavy oil components, and after heavy oil components are connected to a viscosity reducer main body in a stable covalent bond mode, cyclodextrin on the viscosity reducer main body and benzyl hydrophobic groups on a guest are self-assembled; under the traction action of the guest hydrophilic polymer chain, the large pi bond formed by aromatic polycyclic conjugation between the heavy oil polymer aggregates is destroyed, and smaller heavy oil polymer aggregates are formed.

The diameter of the dispersed emulsified oil drops is far smaller than the diameter of the pore throat which mainly contributes to the permeability, and meanwhile, the liquid phase formed after the thick oil is emulsified has smaller apparent viscosity, so that the flowing capacity of the thick oil is improved, and the oil displacement efficiency is improved.

Therefore, when the influence of the temperature-sensitive compound profile control system on the oil reservoir injection and extraction scheme is considered, the change of the data field of each component of each grid block in the oil reservoir simulation model is considered in the working process of the oil reservoir exploitation model under the influence of the temperature-sensitive compound profile control system.

For example, an oil reservoir exploitation model is established according to preset oil reservoir parameters, wherein 29 grids are arranged in the X direction of the oil reservoir exploitation model, 31 grids are arranged in the Y direction, 5 grids are arranged in the Z direction, the plane grid step length of the oil reservoir exploitation model is 10m, and the longitudinal grid step length is not 0.7m; the porosity pair of the oil deposit exploitation model is 0.32, the plane permeability is 1300mD, the longitudinal permeability is 0.5 times of the plane permeability, the initial oil saturation is 0.65, when the oil deposit exploitation model is set to 1 injection and 2 exploitation, the injection speed is 0.1PV/a, and the oil deposit exploitation ratio is 1.1:1, the oil deposit can be produced for 12 years according to the oil deposit exploitation model result.

Fig. 5 is a comparison chart of recovery ratio without considering characteristics of a temperature-sensitive compound profile control system and with considering characteristics of the temperature-sensitive compound profile control system according to an embodiment of the present application. As shown in fig. 5, the simulation results indicate that:

When the characteristics of the temperature-sensitive composite profile control system are not considered, the temperature-sensitive viscoelastic polymer profile control agent only has the viscosity which changes along with the concentration as the common polymer, and the fluidity control effect of the temperature-sensitive viscoelastic polymer profile control agent cannot be exerted because the water phase viscosity is further increased when the temperature of the temperature-sensitive viscoelastic polymer profile control agent is not calculated by an oil reservoir exploitation model and is increased from the ground temperature to the oil reservoir temperature; the water-soluble viscosity reducer injected subsequently is similar to a surfactant, and cannot reflect the effect of improving the flow capacity of a displaced phase (crude oil) due to chemical viscosity reduction; meanwhile, the traditional capillary number model is not suitable for describing the relation between the phase permeation endpoint value and the temperature-sensitive compound profile control system parameter under the condition, and the synergistic interaction between chemical agents is ignored.

Therefore, when the characteristics of the temperature-sensitive compound profile control system are not considered, the water content of the simulation prediction calculation result is high, and the recovery ratio is low.

When the characteristics of the temperature-sensitive composite profile control and flooding system are considered, the viscosity of the temperature-sensitive viscoelastic polymer profile control agent component is rapidly and greatly increased along with the temperature rise, so that the water phase flow resistance in the simulation process is increased, the hypertonic channel is blocked, and the sweep is enlarged; the water-soluble viscosity reducer is characterized in that after the crude oil is subjected to an emulsification reaction, the apparent viscosity of the generated emulsified oil component is greatly reduced, the flowing capability of an oil phase is improved, the saturation of residual oil in partial pores in a sweep region is reduced, and the oil washing efficiency is improved; finally, due to the synergistic effect among the chemical agents, the recovery ratio increase of the analog calculation temperature-sensitive compound flooding system is larger than that of a single chemical agent, and the single flooding of the chemical agents is larger than that of the sum of the recovery ratio increases.

Simulation results show that the temperature-sensitive compound profile control system has obvious influence on oil displacement efficiency, an effect rule and a development effect, and needs to be fully valued in actual oil reservoir numerical simulation research to accurately evaluate oil field development potential, deepen the oil displacement rule of the temperature-sensitive compound profile control system, obtain a better oil reservoir injection and production scheme and guide the optimized deployment of the oil field development scheme.

In this embodiment, when the characteristics of the temperature-sensitive compound profile control system are considered, the specific embodiment process of the method steps may refer to embodiment one, and the description of this embodiment is not repeated here.

Example III

Fig. 6 is a connection block diagram of an oil reservoir injection and production optimization device 200 according to an embodiment of the present application, where the device 200 shown in fig. 6 includes:

A model construction module 201, the model construction module 201 being configured to establish an oil reservoir production model based on oil reservoir parameters, obtain an initial data field for each of the grid blocks in the oil reservoir production model, wherein the data fields include a saturation data field, a pressure data field, a temperature data field, a viscosity data field, and a relative permeability data field;

A first data acquisition module 202, wherein the first data acquisition module 202 is configured to acquire a cumulative flow rate of each grid block in the oil reservoir exploitation model, and obtain a first saturation data field, a first temperature data field and a first pressure data field in each grid block according to the cumulative flow rate;

a second data acquisition module 203, wherein the second data acquisition module 203 is configured to acquire a first viscosity data field of the aqueous phase in each grid block according to a relation model of the viscosity of the aqueous phase and the concentration and temperature change of the temperature-sensitive plugging agent component;

A third data acquisition module 204, wherein the third data acquisition module 204 is configured to obtain an oil phase second viscosity data field, an oil phase second saturation data field, an aqueous phase second viscosity data field, and an aqueous phase second saturation data field in each grid block according to a chemical reaction relation model of the viscosity reducer component in the aqueous phase and the crude oil component in the oil phase;

A fourth data acquisition module 205, wherein the fourth data acquisition module 205 is configured to acquire a first water phase relative permeability data field in each grid block according to a relation model of the adsorption amount of the temperature-sensitive plugging agent component in the water phase per unit pore volume and the change of the water phase relative permeability;

A fifth data acquisition module 206, the fifth data acquisition module 206 configured to obtain a first oil phase relative permeability data field according to a model of a variation relationship of the oil phase relative permeability data field with the number of capillaries;

a sixth data acquisition module 207, the sixth data acquisition module 207 being configured to obtain updated data fields from the first saturation data field, first temperature data field and first pressure data field, the aqueous phase first viscosity data field, the oil phase second viscosity data field, oil phase second saturation data field, aqueous phase second viscosity data field and aqueous phase second saturation data field, first aqueous phase relative permeability data field, first oil phase relative permeability data field;

The control module 208 is configured to control the oil reservoir exploitation model to perform iterative computation within a preset time according to replacing the initial data field in the oil reservoir exploitation model with the updated data field, so as to obtain a second water phase relative permeability and a second oil phase relative permeability;

An optimization module 209, the optimization module 209 configured to optimize reservoir injection and production based on the second aqueous phase relative permeability and second oil phase relative permeability.

Further, the model construction module 201 builds a reservoir recovery model based on the reservoir parameters and equation (1).

Further, the model building module 201 builds an oil reservoir exploitation model based on the oil reservoir parameters, and obtains an initial data field of each grid block in the oil reservoir exploitation model, including: and acquiring a data field of all components of each phase of each grid block in the oil reservoir exploitation model.

Further, the first data obtaining module 202 obtains a cumulative flow rate of each grid block in the oil reservoir exploitation model, and obtains a first saturation data field, a first temperature data field and a first pressure data field in each grid block according to the cumulative flow rate, including:

Further, the second data obtaining module 203 obtains the first viscosity data field of the aqueous phase in each grid block according to a relationship model of the viscosity of the aqueous phase and the concentration and the temperature change of the temperature-sensitive plugging agent component, including:

And obtaining a first viscosity field of the aqueous phase in each grid block based on a calculation formula (6) according to the viscosity of the temperature-sensitive plugging agent component and the viscosity of the aqueous phase component after the temperature-sensitive plugging agent is added into each grid block.

Further, the third data obtaining module 204 obtains the oil phase second viscosity data field, the oil phase second saturation data field, the water phase second viscosity data field, and the water phase second saturation data field in each grid block according to a chemical reaction relation model of the viscosity reducer component in the water phase and the crude oil component in the oil phase, including:

the viscosity reducer component in the aqueous phase and the crude oil component in the oil phase are obtained according to a chemical reaction formula in the chemical reaction process, wherein the oil phase second viscosity data field, the oil phase second saturation data field, the aqueous phase second viscosity data field and the aqueous phase second saturation data field are obtained in each grid block.

Further, the fourth data obtaining module 205 obtains the first aqueous phase relative permeability data field of the aqueous phase in each grid block according to a relation model of the adsorption amount of the temperature-sensitive plugging agent component in the unit pore volume and the change of the aqueous phase relative permeability, including:

And acquiring a first water phase relative permeability data field in each grid block based on a calculation formula (9) according to the adsorption quantity of the temperature-sensitive plugging agent component in the unit pore volume and the water phase relative permeability of each grid water phase.

The specific embodiment process of the above method steps can be referred to the first embodiment and the second embodiment, and the description of this embodiment is not repeated here.

Example IV

The present embodiment also provides a computer readable storage medium, such as a flash memory, a hard disk, a multimedia card, a card memory (e.g., SD or DX memory, etc.), a Random Access Memory (RAM), a Static Random Access Memory (SRAM), a read-only memory (ROM), an electrically erasable programmable read-only memory (EEPROM), a programmable read-only memory (PROM), a magnetic memory, a magnetic disk, an optical disk, a server, an App application store, etc., on which a computer program is stored, which when executed by a processor, can implement the steps of the method according to the first embodiment and the second embodiment, and the description of the present embodiment is not repeated herein.

Example five

The electronic device provided by the embodiment of the application can comprise: and the processor is connected with the memory in a communication way.

Wherein the memory has stored thereon a computer program which, when executed by the processor, performs all or part of the steps of the reservoir injection and production optimization method as in embodiment one.

Specifically, the Processor may be an Application SPECIFIC INTEGRATED Circuit (ASIC), a digital signal Processor (DIGITAL SIGNAL Processor, DSP), a digital signal processing device (DIGITAL SIGNAL Processing Device, DSPD), a programmable logic device (Programmable Logic Device, PLD), a field programmable gate array (Field Programmable GATE ARRAY, FPGA), a controller, a microcontroller, a microprocessor, or other electronic components for implementing the reservoir injection and production optimization method in the above embodiment one.

In particular, the Memory may be implemented by any type of volatile or non-volatile Memory device or combination thereof, such as static random access Memory (Static Random Access Memory, SRAM for short), electrically erasable programmable Read-Only Memory (ELECTRICALLY ERASABLE PROGRAMMABLE READ-Only Memory, EEPROM for short), erasable programmable Read-Only Memory (Erasable Programmable Read-Only Memory, EPROM for short), programmable Read-Only Memory (Programmable Read-Only Memory, PROM for short), read-Only Memory (ROM for short), magnetic Memory, flash Memory, magnetic disk or optical disk.

In summary, the method, the device, the storage medium and the electronic equipment for optimizing oil reservoir injection and production provided by the application comprise the following steps: step S110: establishing an oil reservoir exploitation model based on oil reservoir parameters, and acquiring an initial data field of each grid block in the oil reservoir exploitation model, wherein the data fields comprise a saturation data field, a pressure data field, a temperature data field, a viscosity data field and a relative permeability data field; step S120: acquiring accumulated flow of each grid block in the oil reservoir exploitation model, and acquiring a first saturation data field, a first temperature data field and a first pressure data field in each grid block according to the accumulated flow; step S130: obtaining a first viscosity data field of the aqueous phase in each grid block according to a relation model of the aqueous phase viscosity and the temperature change of the temperature-sensitive plugging agent component concentration and the temperature change; step S140: obtaining an oil phase second viscosity data field, an oil phase second saturation data field, an aqueous phase second viscosity data field and an aqueous phase second saturation data field in each grid block according to a chemical reaction relation model of a viscosity reducer component in the aqueous phase and a crude oil component in the oil phase; step S150: acquiring a first water phase relative permeability data field in each grid block according to a relation model of the adsorption quantity of a temperature-sensitive plugging agent component in the water phase in unit pore volume and the change of the water phase relative permeability; step S160, obtaining a first oil phase relative permeability data field according to a relation model of the oil phase relative permeability data field along with the change of the capillary number; step S170: obtaining updated data fields according to the first saturation data field, the first temperature data field, the first pressure data field, the water phase first viscosity data field, the oil phase second saturation data field, the water phase second viscosity data field, the water phase second saturation data field, the first water phase relative permeability data field and the first oil phase relative permeability data field; step S180: replacing the initial data field in the step S120 with the updated data field, and circularly executing the steps S120-S170 within preset time to obtain a second water phase relative permeability and a second oil phase relative permeability; step S190: and optimizing oil reservoir injection and production based on the second water phase relative permeability and the second oil phase relative permeability.

According to the method, an oil reservoir exploitation model is established based on oil reservoir parameters, a change rule of viscosity after the temperature-sensitive plugging agent component exists in each grid block is represented by a relation model of water phase viscosity and temperature-sensitive plugging agent component concentration and temperature change, a chemical relation model of water-soluble plugging agent component and original components in an oil phase represents a chemical viscosity reduction process, a change rule of an oil phase relative permeability curve is corrected along with the change relation model of improved capillary number, a data field in each grid is updated in the iterative calculation process of the oil reservoir exploitation model, accuracy of a numerical simulation prediction result of oil reservoir injection and exploitation under the influence of characteristics of a sensitive composite plugging agent is improved, accuracy and reliability of oil reservoir injection and exploitation are guaranteed, and powerful support is provided for reasonably optimizing oil field exploitation technical policies, accurately evaluating oil reservoir exploitation potential and effectively making an oil reservoir exploitation scheme.

In the embodiments provided in the present application, it should be understood that the disclosed method may be implemented in other manners. The method embodiments described above are merely illustrative.

It should be noted that, in this document, the terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, an element defined by the phrase "comprising one … …" does not exclude the presence of other like elements in a process, method, article, or apparatus that comprises an element.

Although the embodiments of the present application are described above, the above description is only for the convenience of understanding the present application, and is not intended to limit the present application. Any person skilled in the art can make any modification and variation in form and detail without departing from the spirit and scope of the present disclosure, but the scope of the present disclosure is still subject to the scope of the appended claims.

Claims

1. A method for optimizing oil reservoir injection and production, the method comprising:

Step S160: obtaining a first oil phase relative permeability data field according to a relation model of the oil phase relative permeability data field along with the change of the capillary number;

Step S180: replacing the initial data field in the step S110 with the updated data field, and circularly executing the steps S120-S170 within preset time to obtain a second water phase relative permeability and a second oil phase relative permeability;

2. The method of claim 1, wherein the establishing a reservoir production model based on reservoir parameters comprises:

Based on the following calculation formula:

3. The method according to claim 1, wherein said step S110: establishing an oil deposit exploitation model based on oil deposit parameters, and acquiring an initial data field of each grid block in the oil deposit exploitation model, wherein the initial data field comprises the following steps: and acquiring a data field of all components of each phase of each grid block in the oil reservoir exploitation model.

4. The method according to claim 1, wherein the step S120: acquiring the accumulated flow of each grid block in the oil reservoir exploitation model, and acquiring a first saturation data field, a first temperature data field and a first pressure data field in each grid block according to the accumulated flow, wherein the method comprises the following steps:

and respectively acquiring a first saturation data field, a first temperature data field and a first pressure data field of each phase in all directions of each grid block according to the accumulated flow and the state equation of each phase in all directions of each grid block.

5. The method according to claim 1, wherein said step S130: obtaining a first viscosity data field of the water phase in each grid block according to a relation model of the viscosity of the water phase and the concentration and temperature change of the temperature-sensitive plugging agent component, wherein the first viscosity data field comprises:

6. The method according to claim 1, wherein said step S140: obtaining an oil phase second viscosity data field, an oil phase second saturation data field, an aqueous phase second viscosity data field and an aqueous phase second saturation data field in each grid block according to a chemical reaction relation model of a viscosity reducer component in the aqueous phase and a crude oil component in the oil phase, wherein the method comprises the following steps:

7. The method according to claim 1, wherein said step S150: obtaining a first water phase relative permeability data field of the water phase in each grid block according to a relation model of the adsorption quantity of the temperature-sensitive plugging agent component in the water phase in unit pore volume and the change of the relative permeability of the water phase, wherein the data field comprises the following components:

8. An oil reservoir injection and production optimizing device, comprising:

A model building module configured to build an oil reservoir production model based on oil reservoir parameters, obtain an initial data field for each grid block in the oil reservoir production model, wherein the data fields include a saturation data field, a pressure data field, a temperature data field, a viscosity data field, and a relative permeability data field;

an optimization module configured to optimize a reservoir injection and production scheme based on the second aqueous phase relative permeability and second oil phase relative permeability.

9. A storage medium storing a computer program executable by one or more processors for implementing the reservoir injection and production optimization method of any one of claims 1-7.

10. An electronic device comprising a memory and a processor, wherein the memory has stored thereon a computer program, the memory and the processor being communicatively coupled to each other, the computer program, when executed by the processor, performing the reservoir injection and production optimization method of any one of claims 1-7.