CN115506759A - CO (carbon monoxide) 2 Optimization method of surfactant alternating injection parameters and application of optimization method in medium-high permeability oil reservoir - Google Patents
CO (carbon monoxide) 2 Optimization method of surfactant alternating injection parameters and application of optimization method in medium-high permeability oil reservoir Download PDFInfo
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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
- E21B43/164—Injecting CO2 or carbonated water
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Abstract
The invention belongs to the field of development of oil and gas fields, and particularly relates to CO 2 An optimization method of surfactant alternate injection parameters and application in medium-high permeability oil reservoirs. The method comprises the following steps: establishing a three-dimensional geological model and a numerical simulation model of the test area, introducing physicochemical parameters into the numerical simulation model on the basis of production history fitting, and establishing three-dimensional CO of the test area 2 Surfactant flooding numerical simulation model, by protocol comparison, optimal injection parameters are preferred. The process of the invention enables the binding of CO 2 Displacing and surfactant displacingHas the advantages that the alternate injection of high frequency and small section plugs under the condition of small well spacing is beneficial to exerting CO 2 And the synergistic effect of flooding and surfactant flooding controls gas channeling, enlarges swept volume and improves the recovery ratio of crude oil.
Description
Technical Field
The invention belongs to the field of development of oil and gas fields, and particularly relates to CO 2 An optimization method of surfactant alternate injection parameters and application in medium-high permeability oil reservoirs.
Background
The improvement of the water flooding development effect of the oil field in the high water cut period is always the research focus in the field of oil and gas exploitation at home and abroad. On the basis of the fine description of an oil reservoir and the research of the distribution of residual oil, the development effect is improved by adopting an enhanced oil recovery technology, a well pattern optimization technology, a water injection adjustment technology, a special drilling technology, an oil reservoir deep profile control technology and the like. The measures are mainly aimed at a self-contained oil field or a fault block oil field with large reserve, and the application of the measures to small fault blocks has technical limitation.
According to the present inventionThe literature in the table improves the water flooding development effect of the high-water-cut oil reservoir, develops more chemical flooding applications, and mainly takes polymer flooding, binary flooding, ternary flooding and the like as main materials. The technologies are suitable for the implementation of the whole-loading or large-reserve fault block oil reservoir, and have technical and economic limitations on the small fault blocks with low reserve, high salt content and high calcium and magnesium content in formation water. Foreign CO 2 The development is early, and the United states has led to CO for the past decades 2 And (5) the increase of oil displacement projects. The domestic Jilin oil field, the Huadong grass house oil field, the original Pucheng oil field, the northeast Yaying platform oil field, the Jiangsu Fumin oil field, the Jidong oil field and the like successively develop CO of a plurality of well groups 2 The field test is driven, and the preliminary effect and the knowledge are obtained. For high water content, high permeability and crack oil reservoir CO 2 The effect of the drive is limited. Domestic and overseas supply of CO 2 The combination with chemical agent is mainly used for generating foam, delaying gas channeling, improving gas drive and enlarging sweep efficiency. The measures for sealing the channeling are relatively small in dosage of the chemical agent and design of the slug, and the oil washing performance of the chemical agent is not considered, and only the foaming effect is concerned.
For medium-high-permeability high-water-content complex fault oil reservoirs, the formation water has high content of calcium and magnesium ions and is limited by chemical flooding. Conventional CO at small well spacing 2 Flooding, chemical flooding and large slug WAG injection modes have technical limitations.
Disclosure of Invention
The invention aims to solve the problems, aims at the main contradiction of exposure in the development of high water-cut oil reservoirs, and aims at solving the problems that water cut rises quickly, yield decreases quickly and the like; the formation water is high in salt and calcium and magnesium, and the chemical flooding application is limited; small well spacing and small fault block oil reservoir CO 2 The problem of small enhanced recovery rate amplitude and the like in the flooding, particularly in the conventional water-gas alternative injection mode; providing a CO 2 CO in composite oil displacement technology 2 The method is favorable for obtaining a displacement method which can inhibit the gas-oil ratio from rising, enlarge sweep efficiency and obviously improve the recovery ratio under the condition that other parameters are not changed.
To achieve the above object, a first aspect of the present invention provides a CO 2 -alternate surfactant injection parametersOptimization method of the CO 2 The surfactant alternate injection parameter optimization method comprises the following steps:
(1) Establishing a three-dimensional geological model of the oil reservoir in the test area and a numerical simulation model of the oil reservoir in the test area, performing production history fitting on the numerical simulation model of the oil reservoir in the test area, designing a numerical simulation prediction scheme for improving the recovery ratio at the maximum amplitude on the numerical simulation model in the test area, and developing CO 2 -surfactant flooding optimization studies;
(2) Performing simulation calculation on the designed numerical simulation prediction scheme by using the test area numerical simulation model, comparing the development effect and determining CO 2 -an optimal range of surfactant alternating injection parameters;
(3) Establishing all the numerical simulation models and carrying out numerical simulation research to complete CO 2 Optimizing the parameters of the alternative injection of the surfactant and determining the injection scheme for improving the recovery ratio at the maximum amplitude.
Preferably, the CO is selected prior to screening the reservoir in the test area 2 The surfactant alternate injection parameter optimization method further comprises the following steps:
establishing a core scale numerical simulation model, performing displacement experiment fitting on the core scale numerical simulation model, and correcting physicochemical parameters through the displacement experiment fitting;
the displacement experiment fitting comprises optional water displacement experiment fitting, surfactant displacement experiment fitting, and CO 2 Displacement experiment fitting, CO 2 -fitting of surfactant complex displacement experiments;
the physicochemical parameters comprise fluid PVT phase state, surfactant concentration, viscosity of corresponding aqueous solution under reference pressure, surfactant concentration, oil-water interfacial tension, set miscible related parameters, adsorption and desorption of the surfactant on rock, and wettability change related parameters.
As a preferred scheme, the step of establishing the core scale numerical simulation model comprises the following steps:
A. extracting physicochemical parameters and experimental conditions of a physical simulation experiment;
B. establishing a grid type, a grid size and a grid step length adopted by a core scale numerical simulation model;
C. establishing a numerical simulation model of a rock core scale displacement experiment;
the experimental conditions include: the diameter and length of the core, the porosity and permeability of the core, the viscosity and density of crude oil, the experiment temperature, the experiment pressure, the salinity of formation water and the saturation; and experimental injection data and extraction data at the extraction end, etc.
As a preferred option, CO is carried out 2 Before the research of the surfactant combination flooding optimization, the method further comprises the following steps:
and designing a numerical simulation prediction scheme for improving the recovery ratio by the maximum amplitude on the numerical simulation model of the oil reservoir in the test area by referring to the experimental result of the physical and chemical parameters.
And as an optimal scheme, when the displacement experiment simulation is carried out on the core scale numerical simulation model, the pressure of an injection end, the water content of a production end and the gas-oil ratio of the production end are controlled to be matched with experiment data, and the displacement efficiency calculated by numerical simulation and the error of an experiment value are less than 5%.
Preferably, CO is 2 The surfactant combination flooding optimization research comprises the following steps:
injection agent sequence optimization research, injection mode optimization research, slug size optimization research, slug proportion optimization research, slug concentration optimization research, injection total amount optimization research and injection speed optimization research.
According to the present invention, there is provided,
the injection sequence includes: CO 2 2 Alternate injection with surfactant, surfactant and CO 2 Alternately injecting;
the injection mode comprises the following steps: alternately injecting high-frequency small slugs and low-frequency large slugs;
the slug proportion comprises: CO 2 2 Displacement time ratio of surfactant to displacement time, surfactant displacement and CO 2 The proportion of the driving time;
the slug concentration includes: surfactant concentration;
the total injection amount comprises: CO 2 2 Total amount of injected, total amount of surfactant injected;
the injection speed comprises the following steps: CO 2 2 Injection rate, surfactant injection rate.
According to the invention, CO 2 In the research of the optimization of the surfactant flooding,
the size of the slug is 5-60d;
CO 2 with alternating injection of surfactant, CO 2 The time ratio of flooding to surfactant flooding is 5-60 d: 5-60d;
surfactant and CO 2 In alternate injection, surfactant flooding with CO 2 The time ratio of flooding is 5-60 d: 5-60d;
one round of alternately injecting the high-frequency small section plugs is less than 30 days, and one round of alternately injecting the low-frequency large section plugs is more than or equal to 30 days;
the concentration of the surfactant is 0.3-1.0%;
CO 2 the total injection amount is 0.1PV-0.5PV;
the total amount of the surfactant injected is 0.1-0.5PV;
CO 2 the injection speed is 10 to 40t/d;
the injection speed of the surfactant is 50-120 m 3 /d。
A second aspect of the present invention provides the above CO 2 The application of the surfactant alternate injection parameter optimization method in the medium-high permeability and high water-containing oil reservoir;
the medium-high permeability and high water-bearing oil reservoir meets the requirements that the air permeability is more than 50mD and the comprehensive water content is more than 60 percent.
The invention has the beneficial effects that:
the invention utilizes numerical simulation technology to invent CO 2 Optimization method of surfactant alternating injection parameters, simulation and prediction of CO 2 The application effect of the mine field in the composite displacement technology. The invention is helpful for researching CO 2 The compound displacement mechanism and the influence of different concentrations, different slug sizes, injection sequence, alternate injection mode and the like on the recovery ratio; is helpful for designing better CO 2 The method for improving the crude oil recovery efficiency by compound flooding provides a certain technical reference for the implementation of a mine field.
According to the invention, physical and chemical parameters are imported into a numerical simulation model on the basis of production history fitting, and three-dimensional CO of a test area is established 2 Surfactant flooding numerical simulation model, by protocol comparison, optimal injection parameters are preferred. The process of the invention enables the binding of CO 2 The advantages of flooding and surfactant flooding are that the alternate injection of high frequency and small section of plugs is beneficial to the exertion of CO under the condition of small well spacing 2 And the synergistic effect of flooding and surfactant flooding controls gas channeling, enlarges swept volume and improves the recovery ratio of crude oil.
Additional features and advantages of the invention will be set forth in the detailed description which follows.
Drawings
Figure 1 shows a flow chart of an embodiment of the present invention.
FIG. 2 shows a graph of cumulative oil production for a slug cycle for an example of the present invention versus a comparative example.
Figure 3 shows the gas to oil ratio comparison curves for the inventive examples and comparative examples.
Detailed Description
Preferred embodiments of the present invention will be described in more detail below. While the following describes preferred embodiments of the present invention, it should be understood that the present invention may be embodied in various forms and should not be limited by the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the invention to those skilled in the art.
A first aspect of the invention provides a CO 2 Method for optimizing the parameters of the alternate injection of surfactant, CO 2 The optimization method of the alternate surfactant injection parameters comprises the following steps:
(1) Establishing a three-dimensional geological model of the oil deposit in the test area and a numerical simulation model of the oil deposit in the test area, performing production history fitting on the numerical simulation model of the oil deposit in the test area, designing a numerical simulation prediction scheme for improving the recovery ratio by the maximum amplitude on the numerical simulation model of the test area, and developing CO 2 -surfactant flooding optimization studies;
(2) Numerical simulation using test zonesModel, carrying out simulation calculation on the designed numerical simulation prediction scheme, comparing development effects, and determining CO 2 -optimal range of surfactant alternating injection parameters;
(3) Establishing all the numerical simulation models and carrying out numerical simulation research to finish CO 2 Optimizing the parameters of the alternative injection of the surfactant and determining the injection scheme for improving the recovery ratio at the maximum amplitude.
Preferably, in the step (1), the conditions met by the reservoir in the test area comprise:
the oil deposit temperature is less than 100 ℃, the crude oil viscosity is less than 50cp under the stratum condition, and the crude oil density is less than 0.922g/cm 3 The stratum pressure is more than 0.8 times of MMP, the injection-production well spacing is 80-120 m, and the stratum average permeability is 664-1617mD.
Preferably, the CO is selected prior to screening the reservoir in the test area 2 The surfactant alternate injection parameter optimization method further comprises the following steps:
establishing a core scale numerical simulation model, performing displacement experiment fitting on the core scale numerical simulation model, and correcting physicochemical parameters through the displacement experiment fitting;
the displacement experiment fitting comprises optional water displacement experiment fitting, surfactant displacement experiment fitting, and CO 2 Displacement experiment fitting, CO 2 -surfactant complex displacement experiment fitting;
the physicochemical parameters comprise fluid PVT phase state, surfactant concentration-viscosity of corresponding aqueous solution under reference pressure, surfactant concentration-oil-water interfacial tension, set miscible related parameters, adsorption and desorption of the surfactant on rock, and wettability change related parameters.
As a preferred scheme, the step of establishing the core scale numerical simulation model comprises the following steps:
A. extracting physicochemical parameters and experimental conditions of a physical simulation experiment;
B. establishing a grid type, a grid size and a grid step length adopted by a core scale numerical simulation model;
C. establishing a numerical simulation model of a rock core scale displacement experiment;
the experimental conditions include: the diameter and length of the core, the porosity and permeability of the core, the viscosity and density of crude oil, the experiment temperature, the experiment pressure, the salinity of formation water and the saturation; as well as experimental injection data and production side production data.
As a preferred option, CO is carried out 2 Before the research of the surfactant combination flooding optimization, the method further comprises the following steps:
and designing a numerical simulation prediction scheme for improving the recovery ratio by the maximum amplitude on the numerical simulation model of the oil reservoir in the test area by referring to the experimental result of the physical and chemical parameters.
And as an optimal scheme, when the displacement experiment simulation is carried out on the core scale numerical simulation model, the pressure of an injection end, the water content of a production end and the gas-oil ratio of the production end are controlled to be matched with experiment data, and the displacement efficiency calculated by numerical simulation and the error of an experiment value are less than 5%.
Preferably, CO 2 The surfactant combination flooding optimization study comprises the following steps:
injection agent sequence optimization research, injection mode optimization research, slug size optimization research, slug proportion optimization research, slug concentration optimization research, injection total amount optimization research and injection speed optimization research.
According to the present invention, there is provided,
the injection sequence includes: CO 2 2 Alternate injection with surfactant, surfactant and CO 2 Alternately injecting;
the injection mode comprises the following steps: alternately injecting high-frequency small slugs and low-frequency large slugs;
the slug proportion comprises: CO 2 2 Time ratio of flooding to surfactant flooding, surfactant flooding and CO 2 The proportion of the driving time;
the slug concentration includes: surfactant concentration;
the total injection amount comprises: CO 2 2 Total amount of injected, total amount of surfactant injected;
the injection speed comprises the following steps: CO 2 2 Injection rate, surfactant injection rate.
According to the invention, CO 2 In the research of the optimization of the surfactant combination flooding,
the size of the slug is 5-60d;
CO 2 with alternating injection of surfactant, CO 2 The time ratio of flooding to surfactant flooding is 5-60 d: 5-60d;
surfactant and CO 2 In alternate injection, surfactant flooding with CO 2 The time ratio of flooding is 5-60 d: 5-60d;
one turn of alternate injection of the high-frequency small section plugs is less than 30 days, and one turn of alternate injection of the low-frequency large section plugs is more than or equal to 30 days;
the concentration of the surfactant is 0.3-1.0%;
CO 2 the total injection amount is 0.1-0.5PV;
the total injection amount of the surfactant is 0.1-0.5PV;
CO 2 the injection speed is 10-40 t/d;
the injection speed of the surfactant is 50-120 m 3 /d。
A second aspect of the present invention provides the above CO 2 The application of the surfactant alternate injection parameter optimization method in the medium-high permeability and high water-containing oil reservoir;
the medium-high permeability and high water-bearing oil reservoir meets the requirements that the air permeability is more than 50mD and the comprehensive water content is more than 60 percent.
Example 1
The present example provides a CO 2 Specific application case of the surfactant alternative injection parameter optimization method, a flow chart can be seen in figure 1, and CO is 2 The surfactant alternate injection parameter optimization method comprises the following steps:
(1) Establishing a core scale numerical simulation model, carrying out displacement experiment fitting on the core scale numerical simulation model, and correcting physicochemical parameters through the displacement experiment fitting, wherein the physicochemical parameters comprise fluid PVT phase state, surfactant concentration, viscosity of a corresponding aqueous solution under reference pressure, surfactant concentration, oil-water interfacial tension, set miscible related parameters, adsorption and desorption of a surfactant on rock, and wettability change related parameters. The fitting of the displacement experiment comprises water displacementExperiment fitting, surfactant displacement experiment fitting, CO 2 Displacement experiment fitting, CO 2 -fitting of surfactant complex displacement experiments; verified that CO is 2 Alternate injection of > CO with surfactant 2 Flooding is surfactant flooding is flooding;
the step of establishing the core scale numerical simulation model comprises the following steps:
A. extracting physicochemical parameters and experimental conditions of a physical simulation experiment; the experimental conditions included: manufacturing a sand filling pipe model: a sand filling pipe model manufacturing method is established, sand with two particle sizes (60-80 meshes, 80-100 meshes) is mixed according to the mass ratio of 6 to 4, and a sand filling model (the diameter is 2.5 cm, and the length is 70 cm) with the gas logging permeability of 1400mD can be prepared; simulated oil viscosity: 32.5mpa.s, the mass ratio of crude oil to kerosene is 4; simulating water mineralization degree: 25000mg/L; displacing back pressure: 15MPa; temperature: 74 ℃; oil saturation 56%; the comprehensive water content is 85 percent.
B. Establishing a grid type, a grid size and a grid step length adopted by a core scale numerical simulation model;
C. and establishing a numerical simulation model of the core scale displacement experiment.
When the displacement experiment simulation is carried out on the core scale numerical simulation model, the pressure of the injection end, the water content of the output end and the gas-oil ratio of the output end are controlled to be matched with the experiment data, and the error between the numerical simulation calculation displacement efficiency and the experiment value is less than 5%.
(2) Screening the oil reservoir of the test area, establishing a three-dimensional geological model and a numerical simulation model of the test area, carrying out production history fitting on the numerical simulation model of the test area, referring to the experimental result of physicochemical parameters, designing a numerical simulation prediction scheme for improving the recovery ratio by the maximum amplitude on the numerical simulation model of the test area, and developing CO 2 Surfactant flooding optimization research.
Wherein in step (2), CO 2 The surfactant combination flooding optimization research comprises the following steps:
injection agent sequence optimization research, injection mode optimization research, slug size optimization research, slug proportion optimization research, slug concentration optimization research, injection total amount optimization research and injection speed optimization research.
The injection sequence includes: CO 2 2 Alternately injected with surfactant, surfactant and CO 2 Alternately injecting;
the injection mode comprises the following steps: alternately injecting high-frequency small slugs and low-frequency large slugs;
the slug proportion comprises: CO 2 2 Displacement time ratio of surfactant to displacement time, surfactant displacement and CO 2 The proportion of the driving time;
the slug concentration includes: surfactant concentration;
the total injection amount comprises: CO 2 2 Total amount of injected, total amount of surfactant injected;
the injection speed comprises the following steps: CO 2 2 Injection speed, surfactant injection speed.
According to the invention, CO 2 In the research of the optimization of the surfactant flooding,
the size of the slug is 5-60d;
in this example, under the conditions of the total injection amount (specifically 0.4 PV), the injection pressure (specifically 30 MPa), and the bottom hole flow pressure of the production well (specifically 20 MPa), the total injection amount is determined for CO 2 Alternating injection with surfactant, CO 2 The time ratio of flooding to surfactant flooding was set to 5d:5d, 15d:15d, 30d:30d, 30d:60d; for surfactants and CO 2 Alternate injection, surfactant flooding with CO 2 The time ratio of driving is respectively set as 5d:5d, 15d:15d, 30d:30d, 30d:60d; wherein the gas-oil ratio is increased to 3000m 3 /m 3 When this occurs, the gas injection is stopped. The results show that CO 2 The time ratio of flooding to surfactant flooding is 5: at 5d, the accumulated oil yield is highest, the gas channeling is inhibited, and the gas-oil ratio is lowest.
In this example, the surfactant concentrations were set to 0.3%, 0.5%, 0.8%, 1.0%, respectively.
In this example, CO 2 The total injection amount is respectively set to be 0.1PV, 0.2PV, 0.3PV, 0.4PV and 0.5PV;
in this embodiment, the total amount of the surfactant injection is set to 0.1PV, 0.2PV, 0.3PV, 0.4PV, 0.5PV, respectively;
in this example, CO 2 The injection speeds were set to 10t/d, 20t/d, 30t/d, 40t/d, respectively.
In this example, the surfactant injection speeds were set to 50m, respectively 3 /d、70m 3 /d、100m 3 /d、120m 3 /d。
CO 2 The injection rate, surfactant injection rate, and surfactant concentration were designed orthogonally, as shown in table 1.
TABLE 1 implant velocity Quadrature design
FIG. 2 shows a graph of cumulative oil production for different slug cycle periods for examples of the present invention versus comparative examples. From FIG. 2, it can be seen that CO 2 The time ratio of flooding to surfactant flooding is 5: and when the time is 5 days, the cumulative oil production is the highest.
Figure 3 shows the gas to oil ratio comparison curves for the inventive examples and comparative examples. From FIG. 3, it can be seen that CO 2 The time ratio of flooding to surfactant flooding is 5: and 5d, the gas channeling is inhibited, and the gas-oil ratio is lowest.
(3) Performing simulation calculation on the designed numerical simulation prediction scheme by using the test area numerical simulation model, comparing the development effect and determining CO 2 -an optimal value of the surfactant alternating injection parameter; the results show that: optimum mode of injection CO 2 Alternately injecting with surfactant high-frequency small slugs, wherein the slug proportion is 5:5 (unit: day), CO 2 The optimal total injection amount is 0.3PV, the gas injection speed is 10t/d, and the injection speed is 120m 3 D, surfactant concentration 0.5%, and surfactant injection speed of 120m 3 D, total injection amount 0.3PV.
(4) Establishing all the numerical simulation models by using CMG software, performing numerical simulation research, determining the optimal scheme, and completing CO 2 Optimization of the alternate surfactant injection parameters, the results show that: CO injection first 2 The surfactant is injected later than firstPost-injection of CO with surfactant 2 The alternate injection and extraction degree is 4 percent higher; CO injection first 2 Compared with water flooding, the extraction degree of the post-injection surfactant is improved by 13 percent by alternate injection.
While embodiments of the present invention have been described above, the above description is illustrative, not exhaustive, and not limited to the disclosed embodiments. Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the described embodiments.
Claims (10)
1. CO (carbon monoxide) 2 -method for optimizing the parameters of the alternate injection of surfactant, characterized in that the CO is 2 The optimization method of the alternate surfactant injection parameters comprises the following steps:
(1) Establishing a three-dimensional geological model of the oil deposit in the test area and a numerical simulation model of the oil deposit in the test area, performing production history fitting on the numerical simulation model of the oil deposit in the test area, designing a numerical simulation prediction scheme for improving the recovery ratio by the maximum amplitude on the numerical simulation model of the test area, and developing CO 2 -surfactant flooding optimization studies;
(2) Performing simulation calculation on the designed numerical simulation prediction scheme by using the test area numerical simulation model, comparing the development effect and determining CO 2 -an optimal range of surfactant alternating injection parameters;
(3) Establishing all the numerical simulation models and carrying out numerical simulation research to complete CO 2 Optimizing the parameters of the alternative injection of the surfactant and determining the injection scheme for improving the recovery ratio at the maximum amplitude.
2. CO according to claim 1 2 -method for optimizing the parameters of alternate surfactant injection, wherein said CO is introduced before screening the reservoir in the test area 2 The surfactant alternate injection parameter optimization method further comprises the following steps:
establishing a core scale numerical simulation model, performing displacement experiment fitting on the core scale numerical simulation model, and correcting physicochemical parameters through the displacement experiment fitting;
the displacement experiment fitting comprises optional water displacement experiment fitting, surfactant displacement experiment fitting, and CO 2 Displacement experiment fitting, CO 2 Fitting surfactant complex displacement experiments.
3. CO according to claim 2 2 The optimization method of the surfactant alternate injection parameters comprises fluid PVT phase state, surfactant concentration, viscosity of a corresponding aqueous solution under reference pressure, surfactant concentration, oil-water interfacial tension, set phase mixing related parameters, adsorption and desorption of the surfactant on the rock and wettability change related parameters.
4. CO according to claim 3 2 The optimization method of the alternate injection parameters of the surfactant comprises the following steps of establishing a core scale numerical simulation model:
A. extracting physicochemical parameters and experimental conditions of a physical simulation experiment;
B. establishing a grid type, a grid size and a grid step length adopted by a core scale numerical simulation model;
C. establishing a numerical simulation model of a rock core scale displacement experiment;
the experimental conditions include: the diameter and length of the core, the porosity and permeability of the core, the viscosity and density of crude oil, the experiment temperature, the experiment pressure, the salinity of formation water and the saturation; as well as experimental injection data and production end production data.
5. CO according to claim 3 2 Method for optimizing the parameters of the alternating surfactant injection, wherein CO is carried out 2 Before the optimization research of the surfactant combination flooding, the method also comprises the following steps:
and designing a numerical simulation prediction scheme for improving the recovery ratio in the maximum amplitude on a numerical simulation model of the oil reservoir in the test area by referring to the experimental result of the physicochemical parameters.
6. CO according to claim 3 2 And the optimization method of the alternate injection parameters of the surfactant is characterized in that when the displacement experiment simulation is carried out on the core scale numerical simulation model, the injection end pressure, the water content of the production end and the gas-oil ratio of the production end are controlled to be identical with the experiment data, and the error between the displacement efficiency calculated by numerical simulation and the experiment value is less than 5%.
7. CO according to claim 1 2 Method for optimizing parameters of alternate surfactant injection, in which CO is introduced 2 The surfactant combination flooding optimization study comprises the following steps:
injection agent sequence optimization research, injection mode optimization research, slug size optimization research, slug proportion optimization research, slug concentration optimization research, injection total amount optimization research and injection speed optimization research.
8. CO according to claim 7 2 -a method for optimizing the parameters of alternate surfactant injection, wherein,
the injection sequence includes: CO 2 2 Alternate injection with surfactant, surfactant and CO 2 Alternately injecting;
the injection mode comprises the following steps: alternately injecting high-frequency small slugs and low-frequency large slugs;
the slug proportion comprises: CO 2 2 Displacement time ratio of surfactant to displacement time, surfactant displacement and CO 2 The proportion of the driving time;
the slug concentration includes: surfactant concentration;
the total injection amount comprises: CO 2 2 Total amount of injected, total amount of surfactant injected;
the injection speed comprises the following steps: CO 2 2 Injection rate, surfactant injection rate.
9. CO according to claim 8 2 -a method for optimizing the parameters of alternate surfactant injection, wherein,
the size of the slug is 5-60d;
CO 2 with alternating injection of surfactant, CO 2 Surface activity of the oil-displacing agentThe time ratio of agent flooding is 5-60 d: 5-60d;
surfactant and CO 2 In alternate injection, surfactant flooding with CO 2 The time ratio of flooding is 5-60 d: 5-60d;
one round of alternately injecting the high-frequency small section plugs is less than 30 days, and one round of alternately injecting the low-frequency large section plugs is more than or equal to 30 days;
the concentration of the surfactant is 0.3-1.0%;
CO 2 the total injection amount is 0.1-0.5PV;
the total injection amount of the surfactant is 0.1-0.5PV;
CO 2 the injection speed is 10-40 t/d;
the injection speed of the surfactant is 50-120 m 3 /d。
10. CO according to any one of claims 1 to 9 2 The application of the surfactant alternate injection parameter optimization method in the medium-high permeability and high water-containing oil reservoir;
the medium-high permeability and high water-bearing oil reservoir meets the requirements that the air permeability is more than 50mD and the comprehensive water content is more than 60 percent.
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| CN117034804A (en) * | 2023-08-08 | 2023-11-10 | 中国矿业大学(北京) | Prediction method and system for coal mine carbon dioxide sealing and mining-promoting gas model |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN117034804A (en) * | 2023-08-08 | 2023-11-10 | 中国矿业大学(北京) | Prediction method and system for coal mine carbon dioxide sealing and mining-promoting gas model |
| CN117034804B (en) * | 2023-08-08 | 2024-02-23 | 中国矿业大学(北京) | Prediction method and system for coal mine carbon dioxide sealing and mining-promoting gas model |
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