CN113202451B - Calculation method for injection amount of in-situ generated middle-phase microemulsion washing oil system - Google Patents
Calculation method for injection amount of in-situ generated middle-phase microemulsion washing oil system Download PDFInfo
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- 239000004530 micro-emulsion Substances 0.000 title claims abstract description 116
- 238000002347 injection Methods 0.000 title claims abstract description 75
- 239000007924 injection Substances 0.000 title claims abstract description 75
- 238000011065 in-situ storage Methods 0.000 title claims abstract description 28
- 238000005406 washing Methods 0.000 title claims abstract description 21
- 238000004364 calculation method Methods 0.000 title description 4
- 238000000034 method Methods 0.000 claims abstract description 23
- 239000003921 oil Substances 0.000 claims description 51
- 239000004094 surface-active agent Substances 0.000 claims description 41
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 31
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 27
- 238000004519 manufacturing process Methods 0.000 claims description 11
- 238000002474 experimental method Methods 0.000 claims description 9
- 239000010779 crude oil Substances 0.000 claims description 8
- 230000009286 beneficial effect Effects 0.000 claims description 7
- 230000015572 biosynthetic process Effects 0.000 claims description 5
- 239000004064 cosurfactant Substances 0.000 claims description 4
- 238000011161 development Methods 0.000 abstract description 8
- 239000003153 chemical reaction reagent Substances 0.000 abstract description 4
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 22
- 229910052757 nitrogen Inorganic materials 0.000 description 11
- 239000007864 aqueous solution Substances 0.000 description 9
- LRHPLDYGYMQRHN-UHFFFAOYSA-N N-Butanol Chemical compound CCCCO LRHPLDYGYMQRHN-UHFFFAOYSA-N 0.000 description 8
- 230000000694 effects Effects 0.000 description 7
- 238000006073 displacement reaction Methods 0.000 description 6
- 239000004088 foaming agent Substances 0.000 description 6
- 239000003129 oil well Substances 0.000 description 6
- 230000008569 process Effects 0.000 description 5
- 238000010790 dilution Methods 0.000 description 4
- 239000012895 dilution Substances 0.000 description 4
- 230000035699 permeability Effects 0.000 description 4
- 239000003208 petroleum Substances 0.000 description 4
- 229920000642 polymer Polymers 0.000 description 4
- 238000011084 recovery Methods 0.000 description 4
- 238000013461 design Methods 0.000 description 3
- 239000006260 foam Substances 0.000 description 3
- 239000011148 porous material Substances 0.000 description 3
- -1 alkylbenzene sulfonate Chemical class 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 230000001804 emulsifying effect Effects 0.000 description 2
- ZSIAUFGUXNUGDI-UHFFFAOYSA-N hexan-1-ol Chemical compound CCCCCCO ZSIAUFGUXNUGDI-UHFFFAOYSA-N 0.000 description 2
- 238000002360 preparation method Methods 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 description 2
- 238000012546 transfer Methods 0.000 description 2
- 238000004458 analytical method Methods 0.000 description 1
- 239000012752 auxiliary agent Substances 0.000 description 1
- 238000004422 calculation algorithm Methods 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 230000009977 dual effect Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 229920002521 macromolecule Polymers 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 238000010587 phase diagram Methods 0.000 description 1
- 230000015227 regulation of liquid surface tension Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 230000003381 solubilizing effect Effects 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
- 230000009469 supplementation Effects 0.000 description 1
- 230000009897 systematic effect Effects 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
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Abstract
The invention discloses a method for calculating the injection amount of an in-situ generated middle-phase microemulsion washing oil system, which comprises the following steps: determining the optimal middle-phase microemulsion ratio by using a critical microemulsion curve fitting function, and configuring a middle-phase microemulsion oil-washing system according to the optimal middle-phase microemulsion ratio; calculating the injection radius of the in-situ middle-phase microemulsion; and calculating the injection amount of the middle-phase microemulsion washing oil system according to the injection radius. The method is suitable for most oil reservoirs needing to be injected with microemulsion for development, and the optimal injection concentration of the reagent is determined by the method according to the optimal microemulsion components of different oil reservoirs, so that the in-situ generation and injection of the middle-phase microemulsion oil-washing system are facilitated, and the injection amount of the middle-phase microemulsion oil-washing system is conveniently determined.
Description
Technical Field
The invention relates to the field of middle-phase microemulsion. More particularly, the invention relates to a method for calculating the injection amount of an in-situ generated phase micro-emulsion oil-washing system.
Background
At present, low permeability oil fields mainly adopt water flooding development as a main part and have low recovery rate. As the national demand for petroleum energy increases, the production requirements for low permeability oil fields are also increasing. With the increasing of the oil development strength, the development of heavy oil and the tertiary exploitation of oil reservoirs are more and more important, and especially when low-permeability oil reservoirs are usually exploited by water injection development, polymer macromolecules are difficult to enter the low-permeability oil reservoir due to the characteristics of narrow pore throats, severe reservoir heterogeneity, high injection pressure and the like of the low-permeability oil reservoirs.
In the water injection development process, the injected water has high oil displacement pressure difference, and part of water injection well groups show that the oil increase of corresponding oil wells is not increased, so that the water injection development effect is poor. It is desirable to reduce the displacement pressure difference by reducing the oil-water interfacial tension and reducing the reservoir oil saturation. Aiming at the situation, the microemulsion oil displacement technology of the low-permeability reservoir is adopted by most reservoirs so as to develop the low-permeability oil field reasonably and efficiently.
Different combinations of surfactants and co-surfactants were used for different situations. The invention provides a novel microemulsion system for profile control and flooding, which has good interfacial activity and water and profile plugging effects, has dual effects of oil displacement and profile control, can meet the requirements of field operation for improving the crude oil recovery rate in tertiary oil recovery of low-permeability oil reservoirs, and has good economical efficiency. The proportion of corresponding reagents is provided, and the preparation method of the microemulsion system for profile control and flooding of the low-permeability reservoir is provided. In the invention patent, firstly, injecting a certain volume of nitrogen into an oil well to form a preposed nitrogen slug, then injecting a certain volume of mixed system of the nitrogen and a gel foaming agent aqueous solution into the oil well according to the volume ratio of the nitrogen to the gel foaming agent aqueous solution of 1: 1-3: 1 to form a gel nitrogen foam slug, then injecting a certain volume of mixed system of the nitrogen and a polymer foaming agent aqueous solution into the oil well according to the volume ratio of the nitrogen to the polymer foaming agent aqueous solution of 1: 1-3: 1 to form a polymer nitrogen foam slug, then injecting a certain volume of in-situ microemulsion aqueous solution into the oil well to form an in-situ microemulsion slug, and finally injecting a certain volume of mixed system of the nitrogen and the gel foaming agent aqueous solution into the oil well according to the volume ratio of the nitrogen to the gel foaming agent aqueous solution of 1: 1-3: 1, a gel nitrogen foam slug was formed. The method introduces related steps in a detailed way, and can also not describe related parameters of the preparation and injection process of the microemulsion in a systematic detail way. In the journal article, "evaluation of microemulsion depressurization and stimulation effects of ultra-low permeability reservoir in Honghe oilfield" in Petroleum geology and engineering, "microemulsion combinations with the most use value are determined by comparing microemulsions with different concentrations, and at the same time, the microemulsions can reduce oil saturation by reducing oil-water interfacial tension and solubilizing crude oil, thereby achieving the purposes of reducing water flooding pressure and improving oil flooding effect. But no method for injecting oil reservoirs in production application is given; in journal article optimization and performance research of low permeability reservoir microemulsion formula, petroleum sulfonate with 1.0% of surfactant is screened out through indoor experiments, so that the interfacial tension of an aqueous solution can be reduced to 29.8mN/m, the emulsifying performance reaches 95%, and the method is an optimal condition for forming microemulsion; calculating to obtain the optimal formula mass fraction according to the actual situation of the sunward ditch oil field by using an equation coefficient method, wherein the optimal formula mass fraction is as follows: 1% of petroleum sulfonate, 1% of n-butyl alcohol and 1.38% of n-hexyl alcohol, and the volume ratio of the simulated formation water to the Maoyang ditch dehydrated and degassed crude oil is 4: 1. In journal article "surfactant microemulsion flooding exploration based on oil field current situation", the interfacial property and emulsifying property of a complex system of an anionic-nonionic Gemini surfactant and alkylbenzene sulfonate are researched, the microemulsion content is measured, the optimal complex ratio is determined to be 4:1, on the basis, the optimal auxiliary agent is determined to be n-butyl alcohol according to the formed microemulsion content, and then the optimal microemulsion formula is preferably selected according to the interfacial tension: 0.4% ANG 7-IV-7 and alkylbenzene sulfonate 4:1 mixed system solution/2% n-butanol solution/crude oil. And finally, carrying out different types of microemulsion oil displacement effect analysis experiments in the low-permeability oil field rock core, wherein the recovery ratio of the system reaches 47.3%, the improvement range is the largest, and the effect is the best. The above descriptions are for determining the optimum surfactant, co-surfactant type and ratio in the laboratory, and there is little discussion about the injection process for microemulsion production during production.
Disclosure of Invention
An object of the present invention is to solve at least the above problems and to provide at least the advantages described later.
It is still another object of the present invention to provide a method for creating an injection process design for in-situ generation of a middle-phase microemulsion, which is further needed to develop an experiment for the influence of different surfactant concentrations and different alcohol concentrations on the middle-phase boundary of the microemulsion according to the simulated oil, create an optimal model for injecting the microemulsion into an oil reservoir, design injection parameters, and guide field implementation.
To achieve these objects and other advantages in accordance with the present invention, there is provided a method for calculating an injection amount of an in situ-generated middle phase microemulsion wash oil system, comprising the steps of:
determining the optimal middle-phase microemulsion ratio by using a critical microemulsion curve fitting function, and configuring a middle-phase microemulsion oil-washing system according to the optimal middle-phase microemulsion ratio;
calculating the injection radius of the in-situ middle-phase microemulsion;
and calculating the injection amount of the middle-phase microemulsion washing oil system according to the injection radius.
Preferably, the critical microemulsion curve fitting function is obtained by the following specific steps: and (3) carrying out an experiment on the influence of different surfactant concentrations and different alcohol concentrations on the phase boundary in the microemulsion by using simulated oil to prepare a critical microemulsion curve fitting function with the surfactant concentration as an abscissa and the cosurfactant as an ordinate.
Preferably, the critical microemulsion curve fitting functions are respectively as follows:
Y1＝-0.0094X2+0.1688X+2.6102，R2＝0.9856；
Y2＝0.0115X2-0.0787X+1.562，R2＝0.9908；
wherein X is the concentration of the surfactant, Y is the concentration of the alcohol, and R is the correlation coefficient.
Preferably, the injection radius of the in-situ medium-phase microemulsion is the damage radius in actual production, assuming the damage radius is Rs，
BoIs the volume coefficient of crude oil in the formation, RaAnd G is the ratio of the open hole critical flow M to the perforation critical production H.
Preferably, the injection amount of the middle-phase microemulsion washing oil system is required to satisfy T ═ Q1+Q2T is the amount of middle phase microemulsion needed by the target reservoir, Q1The middle phase microemulsion slug addition, Q, is the most economically beneficial and highest concentration surfactant concentration2Water injection amount for subsequent alcohol addition;
Q1and Q2It is also required to satisfy:
IQ1＝(Q1+Q2)×1％
AQ1+Q2×X＝(Q1+Q2)×J
i is the most economically efficient and highest concentration of surfactant concentration, a is the most economically efficient and highest concentration of co-surfactant (alcohol) concentration, and J is the most economically efficient and lowest concentration of co-surfactant (alcohol) concentration.
The invention at least comprises the following beneficial effects:
the method is suitable for most oil reservoirs needing to be injected with microemulsion for development, and the optimal injection concentration of the reagent is determined by using the method according to the optimal microemulsion components of different oil reservoirs, so that a middle-phase microemulsion oil-washing system can be conveniently generated and injected in situ;
the invention utilizes the simulation oil to develop the experiment of the influence of different surfactant concentrations and different alcohol concentrations on the phase boundary of the microemulsion, establishes the optimal model of injecting the microemulsion into the oil reservoir, designs the injection parameters and guides the field implementation.
Additional advantages, objects, and features of the invention will be set forth in part in the description which follows and in part will become apparent to those having ordinary skill in the art upon examination of the following or may be learned from practice of the invention.
Drawings
FIG. 1 is a schematic diagram of the intersection of a water injection dilution line and a middle-phase microemulsion according to an embodiment of the invention;
FIG. 2 is a schematic diagram of the water injection radius and the water injection speed according to the embodiment of the present invention.
Detailed Description
The present invention is further described in detail below with reference to examples so that those skilled in the art can practice the invention with reference to the description.
It is to be noted that the experimental methods described in the following embodiments are all conventional methods unless otherwise specified, and the reagents and materials are commercially available unless otherwise specified.
The invention provides a method for calculating the injection amount of an in-situ generated middle-phase microemulsion washing oil system, which comprises the following steps:
determining the optimal middle-phase microemulsion ratio by using a critical microemulsion curve fitting function, and configuring a middle-phase microemulsion oil-washing system according to the optimal middle-phase microemulsion ratio;
the method comprises the following specific steps of obtaining a critical microemulsion curve fitting function: carrying out an experiment on the influence of different surfactant concentrations and different alcohol concentrations on phase boundaries in the microemulsion by using simulated oil to prepare a critical microemulsion curve fitting function with the surfactant concentration as an abscissa and the cosurfactant as an ordinate;
the critical microemulsion curve fitting functions are respectively as follows:
Y1＝-0.0094X2+0.1688X+2.6102，R2＝0.9856；
Y2＝0.0115X2-0.0787X+1.562，R2＝0.9908；
wherein X is the concentration of the surfactant, Y is the concentration of the alcohol, and R is the correlation coefficient.
Calculating the injection radius of the in-situ middle-phase microemulsion, wherein the injection radius of the in-situ middle-phase microemulsion is the damage radius in the actual production, and the damage radius is assumed to be Rs，
BoIs the volume coefficient of crude oil in the formation, RaThe radius of a borehole, G is the ratio of the open hole critical flow M to the perforation critical yield H;
h is the critical output of the perforating well, V is the critical seepage velocity, L is the thickness of the oil layer,
the porosity of the core is adopted, and M is the critical flow of the open hole well;
at a critical flow rate Q measured in the laboratory, the critical velocity V is equal to Q divided by the pore area of the medium: namely, it is
V is critical speed, Q is critical flow measured by a laboratory, S is core cross-sectional area,
the porosity of the core is shown, and r is the radius of the core;
in the well bore in actual production, the mixed phase is radial flow, and the critical seepage velocity of the mixed phase is
W is the critical flow at the borehole wall of the perforation section borehole, RaIs the radius of the borehole, L is the thickness of the oil layer,
the core porosity is shown;
to sum up, the critical flow rate Q at the well wallwThe relation with the critical flow Q of the laboratory is
And G is the ratio of the open hole critical flow M to the perforation critical yield H:
m is the open hole critical flow, H is the perforation critical yield, and T is the product of perforation density and perforation radius.
Calculating the injection amount of the middle-phase microemulsion washing oil system according to the injection radius, wherein the injection amount of the middle-phase microemulsion washing oil system needs to meet the requirement that T is Q1+Q2T is the amount of middle phase microemulsion needed by the target reservoir, Q1The middle phase microemulsion slug addition, Q, is the most economically beneficial and highest concentration surfactant concentration2Water injection amount for subsequent alcohol addition;
Q1and Q2It is also required to satisfy:
IQ1＝(Q1+Q2)×1％
AQ1+Q2×X＝(Q1+Q2)×J
i is the most economically efficient and highest concentration of surfactant concentration, a is the most economically efficient and highest concentration of co-surfactant (alcohol) concentration, and J is the most economically efficient and lowest concentration of co-surfactant (alcohol) concentration.
The invention provides an embodiment of a calculation method for generating the injection amount of a phase microemulsion washing oil system in situ.
1. Simulating formation pressure and temperature conditions by using simulated oil, and carrying out an experiment on influences of different surfactant concentrations and different alcohol concentrations on a phase boundary in the microemulsion; determining the surfactant and cosurfactant, and constructing and establishing a model for generating the microemulsion concentration, as shown in figure 1.
The maximum concentration of the injected surfactant (S) and the alcohol (A) of the in-situ generated middle-phase microemulsion is the longest distance which can still maintain the middle-phase microemulsion after being diluted with injected water, namely, the distance between two intersection points A and B of a dilution line of the injected water and a phase diagram of the middle-phase microemulsion is the maximum.
And (3) calculating: y is1＝-0.0094X2+0.1688X+2.6102
Y1’＝-0.0188X+0.1688
Let Y1’＝0
X is 8.9787, the upper curve monotonically increases with the vertex P (8.9787,3.368)
Y2＝0.0115X2-0.0787X+1.562
Y2’＝0.023X-0.0787
Let Y2’＝0
3.4217, lower curve monotonously decreasing vertex Q (3.4217, 1.4274)
Y is X + b, and intersects with the upper curve at P, b1-5.6107; intersects with the lower curve at Q, b2＝-1.9943
Y5＝X-1.9943 intersection with the upper curve O (5.2302,3.2359)
Intercept { (Y)1-Y2)2+(X1-X2)2}0.5＝{2×(X1-X2)2}0.5
The maximum intercept exists at Y4X-5.6107 and Y5X-1.9943.
The trial algorithm comprises the following steps: will Y5When the straight line intersects the upper curve (7.01163, 3.33163) and the lower curve (5.14136, 1.46136), the intercept is maximum, and b-3.68 (7.01163, 3.33163) is the optimum concentration.
Namely, the surfactant concentration is 7.01%, and the surfactant (alcohol) concentration is 3.33%.
2. Calculating the injection radius of the in-situ middle-phase microemulsion
The radius of injection of the in situ generated mid-phase microemulsion needs to be larger than the radius at the reservoir critical injection rate.
At a critical flow rate Q measured in the laboratory, the critical velocity V is equal to Q divided by the pore area of the medium: namely, it is
V is critical speed, Q is critical flow measured by a laboratory, S is core cross-sectional area,
the porosity of the core is shown, and r is the radius of the core;
in the well bore in actual production, the mixed phase is radial flow, and the critical seepage velocity of the mixed phase
W is the critical flow at the borehole wall of the perforation section borehole, RaIs the radius of the borehole, L is the thickness of the oil layer,
the core porosity is defined as;
to sum up, the critical flow rate Q at the well wallwThe relation with the critical flow Q of the laboratory is
And G is the ratio of the open hole critical flow M to the perforation critical yield H:
m is the open hole critical flow, H is the perforation critical yield, and T is the product of perforation density and perforation radius;
the injection radius of the in-situ middle-phase microemulsion is the damage radius in the practical production, and the assumed damage radius is Rs，
BoIs the volume coefficient, R, of the formation crude oilaThe radius of a borehole, G is the ratio of the open hole critical flow M to the perforation critical yield H;
h is the critical output of the perforating well, V is the critical seepage velocity, L is the thickness of the oil layer,
core porosity, and M open hole critical flow.
The experimental value was 0.54mL/min at the critical injection flow rate, and the injection velocity was calculated to be 7.92 m/d. 17.8m in the actual oil layer and 540m in water injection quantity3Under the condition of/d, calculating the relation between the water injection speed and the water injection radius,
as shown in fig. 2, it can be seen from fig. 2 that, at an actual water injection rate and an injection radius of 3.0m, water injection regions with a corresponding water injection rate of 8.05m/d (> 7.92m/d) and less than 3.0m are all regions exceeding the critical water injection rate, and the regions are key regions for reducing pressure and increasing injection in the water injection process of the low-permeability reservoir. Thus, the middle phase microemulsion treatment radius was designed to be 3.0 m.
3. Calculation of injection amount of in-situ formed phase microemulsion
The injection amount of the in-situ generated middle-phase microemulsion needs to be enough that the front end of the middle-phase microemulsion can reach the radius R of a reservoir layer after the transferUAt m, the phase micro-emulsion amount in the target reservoir is required to reach T m3. In order to achieve the most economical and yet maintain a medium phase microemulsion after the lowest point of the dilution line, alcohol supplementation is required to inject water after the most economical and highest surfactant concentration injection to keep the microemulsion in the medium phase at all times. Setting the addition of the phase microemulsion slug with the highest concentration of the surfactant to be Q1The subsequent alcohol addition water injection amount is Q2And the mass concentration of the added alcohol is X, and the following equation set is established:
Q1+Q2＝T
IQ1＝(Q1+Q2)×1％
AQ1+Q2×X＝(Q1+Q2)×J
t is the required middle-phase microemulsion amount of a target reservoir
I is the most economically advantageous and highest concentration of surfactant
A is the most economically efficient and highest concentration of co-surfactant (alcohol)
J is the most economically efficient and lowest concentration of co-surfactant (alcohol).
The injection amount of the in-situ generated middle-phase microemulsion needs to reach 3.0m of reservoir radius at the front end of the middle-phase microemulsion after the transfer injection, and the injection amount of the middle-phase microemulsion needs to reach 100.61m in a target reservoir3. To maintain a medium phase microemulsion after the dilution line reaches point B, the surfactant activity was at 7.01%After the injection of the agent concentration, the injection water needs to be supplemented with alcohol so that the microemulsion is always in the middle phase. The adding amount of the middle-phase microemulsion slug with the concentration of 7.01 percent of surfactant is set as Q1The subsequent alcohol addition water injection amount is Q2And the mass concentration of the added alcohol is X, and the following equation set is established:
Q1+Q2＝100.61
7.01％Q1＝(Q1+Q2)×1％
3.33％Q1+Q2×X＝(Q1+Q2)×1.5％
calculating to obtain the middle-phase microemulsion treatment fluid quantity Q1Is 14.35m3After the middle-phase microemulsion treatment, 86.25m of aqueous solution with the alcohol concentration of 1.2 percent is continuously injected3And then normal water injection is carried out, and reservoirs with the radius of 3.0m are all treated by the middle-phase microemulsion, so that the oil displacement efficiency is more than 98 percent.
While embodiments of the invention have been described above, it is not intended to be limited to the details shown, particular embodiments, but rather to those skilled in the art, and it is to be understood that the invention is capable of numerous modifications and that various changes may be made therein without departing from the spirit and scope of the invention as defined by the appended claims and their equivalents.
Claims (3)
1. A method for calculating the injection amount of an in-situ generated middle-phase microemulsion oil washing system is characterized by comprising the following steps:
determining the optimal middle-phase microemulsion ratio by using a critical microemulsion curve fitting function, and configuring a middle-phase microemulsion oil washing system according to the optimal middle-phase microemulsion ratio;
calculating the injection radius of the in-situ middle-phase microemulsion;
calculating the injection amount of the middle-phase microemulsion oil-washing system according to the injection radius;
the method comprises the following specific steps of obtaining a critical microemulsion curve fitting function: carrying out an experiment on the influence of different surfactant concentrations and different alcohol concentrations on phase boundaries in the microemulsion by using simulated oil to prepare a critical microemulsion curve fitting function with the surfactant concentration as an abscissa and the cosurfactant as an ordinate;
the injection amount of the middle-phase micro-emulsion oil washing system needs to satisfy the requirement that T is Q1+Q2T is the amount of middle phase microemulsion needed by the target reservoir, Q1The middle phase microemulsion slug addition, Q, is the most economically beneficial and highest concentration surfactant concentration2Water injection amount for subsequent alcohol addition;
Q1and Q2It is also required to satisfy:
IQ1＝(Q1+Q2)×1％
AQ1+Q2×X＝(Q1+Q2)×J
i is the most economically beneficial and highest concentration of surfactant concentration, a is the most economically beneficial and highest concentration of co-surfactant concentration, and J is the most economically beneficial and lowest concentration of co-surfactant concentration.
2. The method of calculating the injection volume of an in situ generated mid-phase microemulsion oil system of claim 1, wherein the critical microemulsion curve fitting functions are respectively:
Y1＝-0.0094X2+0.1688X+2.6102，R2＝0.9856；
Y2＝0.0115X2-0.0787X+1.562，R2＝0.9908；
wherein X is the concentration of the surfactant, Y is the concentration of the alcohol, and R is the correlation coefficient.
3. The method for calculating the injection amount of the in-situ generated middle-phase microemulsion oil system according to claim 1, wherein the injection radius of the in-situ middle-phase microemulsion is the damage radius in actual production, and the damage radius is assumed to be Rs，
BoIs the volume coefficient of crude oil in the formation, RaAnd G is the ratio of the open hole critical flow M to the perforation critical yield H.
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