CN109630078A - A kind of layer is interior to generate CO2Transfer drive parameters design method - Google Patents
A kind of layer is interior to generate CO2Transfer drive parameters design method Download PDFInfo
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- CN109630078A CN109630078A CN201811316949.7A CN201811316949A CN109630078A CN 109630078 A CN109630078 A CN 109630078A CN 201811316949 A CN201811316949 A CN 201811316949A CN 109630078 A CN109630078 A CN 109630078A
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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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- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06N—COMPUTING ARRANGEMENTS BASED ON SPECIFIC COMPUTATIONAL MODELS
- G06N3/00—Computing arrangements based on biological models
- G06N3/12—Computing arrangements based on biological models using genetic models
- G06N3/126—Evolutionary algorithms, e.g. genetic algorithms or genetic programming
Abstract
This application discloses generate CO in a kind of layer2Transfer drive parameters design method, which comprises practical oil reservoir is reduced to the multiple zone geological model comprising transfer drive layer reconciliation blocking layer；Inflating medium and bubble release agent dosage are subjected to dynamic splitting, by the difference degree of each substratum injectivity index after analysis transfer drive, inflating medium injection rate, bubble release agent injection rate, inflating medium injection length, bubble release agent injection length and the injection slug number computation model when the injectivity index coefficient of variation minimizes are established；Establish inflating medium, bubble release agent injection pressure computation model；Model above is solved by genetic algorithm.CO is generated in the layer of the application2Transfer drive technique joins design method: profile control agent (inflating medium and bubble release agent) injection rate may be implemented and injection slug number calculates；The real-time prediction that work progress injection pressure may be implemented calculates；Measure effect characterization is intuitive.
Description
Technical field
This application involves oil fields, are espespecially related to generating CO in one of reservoir waterflooding layer2Transfer drive technique ginseng
Number design method.
Background technique
CO is generated in layer2Transfer drive technological parameter mainly includes inflating medium and bubble release agent dosage, slug parameter designing, construction note
Enter pressure and injection discharge capacity.Scientific and reasonable transfer drive process parameters design can be polluted to avoid less permeable layer by blocking agent, most
The improvement intake profile of limits expands swept volume, to improve the validity of transfer drive measure.The dosage of profile control agent is set at present
Meter is mainly include the following types: first is that pressure drop indices P I (pressure index) and reservoir engineering RE (reservoir
Engineering) the profile control agent dosage of decision-making technic determines method, needs the injection test at scene to test and determines use level coefficient, cost
It is high；Second is that method for numerical simulation, needs the processes such as history matching, multistage plug combined prediction, takes a long time；Third is that energy is injected in front and back
Power ratio method needs to be determined in advance the ratio between the water absorbing capacity of transfer drive interval before and after the processing, and flexibility is poor.And profile control agent injection pressure
The design method of power mainly selective injection pressure method, discharge capacity setting method and method for numerical simulation etc..Selective implantation pressure
Force method and discharge capacity setting method need ASP flooding test to determine injection pressure gradient etc., at high cost；Method for numerical simulation need Geologic modeling,
History matching etc., research cycle is long.
Summary of the invention
In order to solve the above-mentioned technical problem, this application provides generate CO in a kind of layer2Transfer drive parameters design method,
The method includes establishing to generate CO in layer2Transfer drive technique Chinese medicine injection rate and injection slug design a model；And it is adopted from note and is
The pressure balance of system is set out, and in conjunction with calculated real time discharge volume, establishes the real-time computation model of work progress injection pressure.To
The design for realizing parameters of construction technology reaches the optimal of dosing and profile modification.
In order to reach the application purpose, this application provides generate CO in a kind of layer2Transfer drive parameters design method, packet
It includes:
(1) practical oil reservoir is reduced to the multiple zone geological model comprising transfer drive layer reconciliation blocking layer；
(2) inflating medium and bubble release agent dosage are subjected to dynamic splitting, pass through the difference of each substratum injectivity index after analysis transfer drive
Off course degree, establish when the injectivity index coefficient of variation minimize when inflating medium injection rate, bubble release agent injection rate, inflating medium injection when
Between, bubble release agent injection length and injection slug number computation model；
(3) inflating medium, bubble release agent injection pressure computation model are established；
(4) model above is solved by genetic algorithm.
In this application, reaction in stratum is injected by water injection well and generates CO2, refer in reservoir formation in the middle layer this paper.
Due to the generally existing difference of reservoir injectivity index, inflating medium and bubble release agent can be selectively penetrated by stratum.Existed according to transfer drive medicament
Thermally coupled flow in stratum, binder course is interior to generate CO2Transfer drive selects layer as a result, practical oil reservoir can be reduced to include " transfer drive layer "
The multiple zone ideal geological model of " solution blocking layer ", is defined as transfer drive layer to the substratum for needing obviously to block in stratum, and needs
Bubble release agent acidification improves formation physical property, while CO2Foam blocking acts on unconspicuous substratum and is defined as solution blocking layer.
After transfer drive measure, since profile control agent acts on the natural selection on stratum, the injectivity index of each transfer drive layer has difference
The degree of irregularity of the reduction of degree, high less permeable layer relative injectivity also constantly reduces, and intake profile is effectively improved.With
The continuous injection of profile control agent, the injectivity index difference of high less permeable layer can be smaller and smaller.When profile control agent total injection reaches one
When determining degree, the injectivity index difference of high less permeable layer can be reduced to minimum value, continue to inject profile control agent, the difference of injectivity index
It will increase instead.Therefore there are an optimal profile control agent dosage, the heterogeneity of intake profile can be improved to greatest extent.
Assuming that the well intake pressure of transfer drive well, injection displacement control are reasonable, all substratums are started, and angry
The performance parameter (including concentration, viscosity, density etc.) of agent and bubble release agent is certain.Water flooding is averaged matter uniform thickness, ignores liquid and rock
The elastic reaction of layer.Target first is that i represents transfer drive layer under agreement digital code, and j represents solution blocking layer.Arrange under digital code
Target first is 1 to represent inflating medium, and 2 represent bubble release agent.
Single note inflating medium process
Transfer drive technique can carry out first it is single infuse inflating medium process, under a certain instantaneous time step, inflating medium is split point always
Amount is equal to the inflating medium discharge capacity v at the moment1(z), the bubble release agent discharge capacity v for splitting point total amount and being equal to the moment of bubble release agent2(z)。
The seepage flow of inflating medium in the earth formation meets linear relationship for seepage.Therefore raw on unit time step on longitudinal profile
The total injection rate of gas agent can use Darcy's law and be split by the injectivity index distribution before transfer drive measure and assigned to each substratum.
In formula: JiFor the injectivity index of transfer drive layer i before transfer drive measure, m3/(h·MPa)；JjTo solve blocking layer j before transfer drive measure
Injectivity index, m3/(h·MPa)；v1It (z) is the discharge capacity of z-th of slug inflating medium, m3/h；n1For the small number of plies of transfer drive layer；n2
For the small number of plies for solving blocking layer；Q1iFor the inflating medium injection rate of transfer drive layer i, m3；kiFor the permeability of transfer drive layer i, mD；hiFor transfer drive
The effective thickness of layer i, m；kjFor the permeability for solving blocking layer i, mD；hjFor the effective thickness for solving blocking layer i, m；μwFor the viscosity of water,
mPa·s；rwFor water injection well wellbore radius, m；reFor drainage radius, m；A is unit conversion coefficient, a=0.0036.
Then, the inflating medium blocking radius under the time step on each substratum can be calculated according to volumetric method:
In formula, rfiFor the inflating medium blocking radius of transfer drive layer i, m；φiFor the porosity of transfer drive layer i.
For transfer drive layer, since inflating medium is the solution of certain carbonate, a large amount of aggregation can also generate weak closure
Effect, therefore in transfer drive layer, caused permeability decrease be can not ignore when singly infusing inflating medium.The plugging action of inflating medium is being adjusted
It drives and forms hypotonic region around layer pit shaft, so as to cause the change of stratum filtration field.According to the variation characteristic of stratum filtrational resistance,
Flow region of the formation fluid in transfer drive layer can be divided into flowing within the scope of from pit shaft to blocking radius and from blocking half
Diameter to supply marginal annular region in flowing.It is possible thereby to calculate the injectivity index J ' of each transfer drive layer after injection inflating mediumi:
In formula: J 'iFor the injectivity index of transfer drive layer after injection inflating medium, m3/(h·MPa)；RRF1For inflating medium remnants resistance
Force coefficient.
Due to ignoring the effect of solution blocking layer inflating medium injection, solution blocking layer injectivity index before and after inflating medium injection is kept
It is constant:
In formula: kjFor the permeability for solving blocking layer, mD；hjFor the effective thickness for solving blocking layer, m；Jj、JjRespectively solution blocking layer is arranged
Apply the injectivity index of front and back, m3/(h·MPa)。
Infuse bubble release agent process
After completing inflating medium injection process, outgassing agent solution can be injected into stratum.Under first time step, bubble release agent
Split point according to each layer injectivity index after inflating medium has been infused in splitting point for each layer.
In formula: J 'iFor the injectivity index of transfer drive layer i after transfer drive measure, m3/(h·MPa)；J′jFor de-plugging after transfer drive measure
The injectivity index of layer j, m3/(h·MPa)；v2It (z) is the discharge capacity of z-th of slug bubble release agent, m3/h；Q2iFor the outgassing of transfer drive layer i
Agent injection rate, m3；Q2J is the bubble release agent injection rate for solving blocking layer j, m3；
Inflating medium is reacted with bubble release agent, generates CO2Foam system, and for solving blocking layer, since remaining oil saturation is higher,
Meet oily defoaming effect, it is possible to calculate according to volumetric method and conciliate by the foam blocking radius under a time step on transfer drive layer
The plug removal radius of blocking layer:
In formula: rfiFor the inflating medium blocking radius of transfer drive layer i, m；rfiFor the foam blocking radius of transfer drive layer i, m；rsjFor
Solve the plug removal radius of blocking layer j, m.
Each layer injectivity index after calculating first time step:
In formula: θ is bubble release agent acidizing degree；RRF is foam residual resistance factor.
Then future time walks, and bubble release agent carries out dosage and splits timesharing, refers to according to each layer water suction after the variation of a upper time step
Number split point.
After sometime walking, the bubble release agent dosage in transfer drive layer is greater than total dosage of inflating medium, i.e.,
The injectivity index calculation formula in transfer drive layer changes at this time, and the acid of bubble release agent also occurs in transfer drive layer at this time
Change effect, transfer drive layer foam blocking radius and bubble release agent acidizing radius can be calculated according to volumetric method:
The injectivity index calculation formula of transfer drive layer reconciliation blocking layer are as follows:
After recycling by slug, the injectivity index final using each substratum is as evaluation index.Each substratum injectivity index is got over
Close, intake profile is more uniform in the injecting process.Therefore in order to reflect the difference degree of the injectivity index of each permeable formation after transfer drive,
Using the coefficient of variation as evaluation index.In statistics, the coefficient of variation is also known as standard rate, is defined as one group of observation data
Standard deviation and mathematic expectaion ratio, that reflects observation data between discrete and difference degree.Therefore suction can be defined
The aqua index coefficient of variation is as follows:
Wherein
In formula:For the mean water absorption index on stratum after transfer drive, m3/(h·MPa)；VJFor the injectivity index coefficient of variation.
The injectivity index coefficient of variation is bigger after transfer drive, illustrates that the water absorbing capacity difference degree of each layer is bigger, intake profile
More uneven, the measure degree that takes effect is lower；Otherwise, intake profile more tends to uniformly, and profile modification is also better.Therefore injectivity index
The construction parameter when coefficient of variation reaches minimum value is that CO is generated in layer2The optimal construction parameter of transfer drive.Design process:
Above formula is substituted into respectively in the formula of the injectivity index coefficient of variation, it can be found that in formation parameter and inflating medium, outgassing
In the case that agent performance parameter is certain, injectivity index coefficient of variation VJIt is inflating medium, bubble release agent discharge capacity v1(z) v2(z), angry
Agent, bubble release agent inject number of days d1 d2, slug number z function, as VJ[v1(z), v2(z), d1, d2, z].Therefore by solving mesh
Scalar functions VJ[v1(z), v2(z), d1, d2, z] minimum value, inflating medium, bubble release agent discharge capacity v can be obtained1 v2, inflating medium,
Bubble release agent injects number of days d1 d2, slug number z best construction parameter.Since objective function is non-linear optimal problem, in order to
It is enough fast and accurately to obtain globally optimal solution, it is solved herein using genetic algorithm.
Inflating medium, bubble release agent injection pressure computation model
In inflating medium and bubble release agent injection process, the pressure of injected system is balance at any time, therefore can root
The pressure equation in work progress is established according to pressure balance principle and seepage theory:
Pwht=Pft+ΔP+Pr-Pht (20)
In formula: PwhtFor medicament well intake pressure, MPa；PhtFor the head of liquid of medicament in the wellbore, MPa；PftFor medicine
The frictional resistance of agent in the wellbore, MPa；Δ P is displacement pressure difference, MPa；PrFor current strata pressure, MPa.
The head of liquid P of medicament in the wellborehtAre as follows:
In formula: ρtFor the density of medicament, g/cm3；H is the depth of transfer drive interval, m.
The frictional resistance P of medicament in the wellboreftAre as follows:
In formula: q is the injection rate of medicament, m3/s；ν is the kinematic viscosity of medicament, m2/s；D is tubing diameter, m；β, m are
The coefficient of friction resistance, value are related with fluid flow state.
Since in transfer drive medicament injection process, Reynolds number is smaller, fluidised form is mainly rendered as laminar flow or two kinds of hydraulically smooth.
When laminar flow, β=4.15, m=1；When hydraulically smooth, β=0.0246, m=0.25.
Displacement pressure differential deltap P are as follows:
In formula: v --- the discharge capacity of medicament, m3/h；
By Pht、ΔPw、ΔP、PftCalculation formula substitute into formula (20), arrange and obtain the calculation formula of well intake pressure:
By formula (24) as it can be seen that in the case where optimum capacity determines, medicament well intake pressure PwhtIt has also determined that.From
And the operation pressure in optimum capacity injection can be calculated and draw operation pressure curve.
Formula (24) is solved such as Fig. 4 using genetic algorithm, basic operation step can be expressed as follows:
(1) initialization operation determines genetic manipulation methods and the crossover probabilities, mutation probability such as selection, intersection, mutation operator
Etc. genetic parameters；
(2) coding strategy is selected, feasible solution set is converted chromosome knob conformational space, generates initial population；
(3) fitness function is defined, convenient for calculating the fitness value of individual；
(4) termination condition judges, if whether group's performance meets a certain index, or is completed scheduled the number of iterations,
Interative computation is then terminated, the operation of (5) step is otherwise transferred to；
(5) selection duplication operation handles population using corresponding selection operator；
(6) crossing operation handles population using corresponding crossover operator；
(7) mutation operator handles population using corresponding mutation operator；
(8) parent population forms next-generation group after the operation of selection, intersection and mutation operator, then goes to step (2).
The design method of the application can also be applied to reservoir waterflooding, the life obtained using the design method of the application
Gas agent dosage, bubble release agent dosage, slug number carry out generating CO in layer2After transfer drive, water injection well water injection rate, accumulation augmented injection obviously increase
Add, the net oil increasing effect of well group oil well is obvious.
Compared to generating CO in conventional layer2Transfer drive technological parameter calculates, and the design method of the application has the advantages that (1)
Profile control agent (inflating medium and bubble release agent) injection rate may be implemented and injection slug number calculates；(2) work progress injection pressure can be achieved
The real-time prediction of power calculates；(3) comprehensively considered static and dynamic factor, calculation method more to match with process characteristic, more
Science.
Other features and advantage will illustrate in the following description, also, partly become from specification
It obtains it is clear that being understood and implementing the application.The purpose of the application and other advantages can be by specifications, right
Specifically noted structure is achieved and obtained in claim and attached drawing.
Detailed description of the invention
Attached drawing is used to provide to further understand technical scheme, and constitutes part of specification, with this
The embodiment of application is used to explain the technical solution of the application together, does not constitute the limitation to technical scheme.
Fig. 1 is " multiple zone " ideal geology model schematic.
Fig. 2 is process parameters design thinking figure.
Fig. 3 is pressure system schematic diagram.
Fig. 4 is genetic algorithm schematic diagram.
Fig. 5 is the curve that operational discharge capacity changes over time in the embodiment of the present application.
Fig. 6 is the curve that operation pressure changes over time in the embodiment of the present application.
Fig. 7 is well water flooding curve of constructing in the embodiment of the present application, and the construction time is on May 24th, 2016 to May 27.
Fig. 8 is well group oil-producing curve of constructing in the embodiment of the present application, and the construction time is on May 24th, 2016 to May 27.
Specific embodiment
For the purposes, technical schemes and advantages of the application are more clearly understood, below in conjunction with attached drawing to the application
Embodiment be described in detail.It should be noted that in the absence of conflict, in the embodiment and embodiment in the application
Feature can mutual any combination.
Embodiment
Below in relation to illustrating General Principle of the invention for water injection well, it should be noted that, the application be not limited to
Lower water injection well.It is calculated using following water injection well data, the basic data of water injection well is as shown in Table 5-1:
The basic data of 1 water injection well of table
| Substratum | Thickness/m | Porosity | Permeability/mD | Day water absorption/m/d | Permeability/mD after correction | Transfer drive/solution blocking layer |
| L30 | 1.3 | 0.247 | 62 | 0 | 50 | Solve blocking layer |
| L40 | 14.5 | 0.287 | 1572.15 | 423.8 | 175.94 | Solve blocking layer |
| L50 | 15.1 | 0.285 | 2206.60 | 3284.45 | 1309.35 | Transfer drive layer |
| L60 | 13.5 | 0.273 | 954 | 1907.1 | 850.37 | Transfer drive layer |
| L70 | 8.5 | 0.246 | 678.01 | 529.75 | 375.16 | Solve blocking layer |
| L80+L90 | 34.6 | 0.256 | 849.14 | 3496.35 | 608.29 | Transfer drive layer |
| L100 | 23.5 | 0.252 | 719.38 | 741.65 | 189.98 | Transfer drive layer |
| L110 | 4.3 | 0.225 | 438 | 211.9 | 296.64 | Solve blocking layer |
It according to calculation formula herein, is solved using genetic algorithm, the result being finally calculated is as follows:
2 water injection well dosage of table
Each slug inflating medium of 3 water injection well of table and bubble release agent discharge capacity
| Slug number | Inflating medium injection rate/m3/h | Bubble release agent injection rate/m3/h |
| 1 | 16.14 | 19.49 |
| 2 | 16.35 | 21.13 |
| 3 | 16.37 | 21.25 |
| 4 | 16.49 | 18.77 |
| 5 | 16.66 | 21.56 |
Water injection well is according to generating CO in design result implementation level in text2Water injection rate is by 982m after transfer drive measure3/ d rises to
1732m3/ d augmented injection 107 days, accumulates augmented injection 39254m3；6 mouthfuls of producing well in well group, wherein taking effect 5 mouthfuls, accumulation has a net increase of oil
8000m3, validity period 5 months.
Although embodiment disclosed by the application is as above, the content only for ease of understanding the application and use
Embodiment is not limited to the application.Technical staff in any the application fields, is taken off not departing from the application
Under the premise of the spirit and scope of dew, any modification and variation, but the application can be carried out in the form and details of implementation
Scope of patent protection, still should be subject to the scope of the claims as defined in the appended claims.
Claims (10)
1. generating CO in a kind of layer2Transfer drive parameters design method, which comprises
(1) practical oil reservoir is reduced to the multiple zone geological model comprising transfer drive layer reconciliation blocking layer；
(2) inflating medium and bubble release agent dosage are subjected to dynamic splitting, pass through the difference journey of each substratum injectivity index after analysis transfer drive
Degree, establish when the injectivity index coefficient of variation minimize when inflating medium injection rate, bubble release agent injection rate, inflating medium injection length,
Bubble release agent injection length and injection slug number computation model；
(3) inflating medium, bubble release agent injection pressure computation model are established；
(4) model above is solved by genetic algorithm.
2. according to the method described in claim 1, wherein, in step (1), being defined to the substratum for needing obviously to block in stratum
For transfer drive layer, while CO2Foam blocking acts on unconspicuous substratum and is defined as solution blocking layer.
3. in step (2), carry out single note inflating medium process first according to the method described in claim 1, wherein, then into
Row note bubble release agent process；Under a certain instantaneous time step, the inflating medium discharge capacity of the inflating medium split point total amount and be equal to the moment
v1(z), the bubble release agent discharge capacity v for splitting point total amount and being equal to the moment of the bubble release agent2(z),
The total injection rate of the inflating medium is split by the injectivity index distribution before transfer drive measure and assigns to each substratum on unit time step:
In formula: JiFor the injectivity index of transfer drive layer i before transfer drive measure, m3/(h·MPa)；JjFor the suction for solving blocking layer j before transfer drive measure
Aqua index, m3/(h·MPa)；v1It (z) is the discharge capacity of z-th of slug inflating medium, m3/h；n1For the small number of plies of transfer drive layer；n2For solution
The small number of plies of blocking layer；QliFor the inflating medium injection rate of transfer drive layer i, m3；kiFor the permeability of transfer drive layer i, mD；hiFor transfer drive layer i's
Effective thickness, m；kjFor the permeability for solving blocking layer i, mD；hjFor the effective thickness for solving blocking layer i, m；μwFor the viscosity of water, mPas；
rwFor water injection well wellbore radius, m；reFor drainage radius, m；A is unit conversion coefficient a=0.0036.
4. according to the method described in claim 3, wherein, during single note inflating medium, injecting after the inflating medium respectively
The injectivity index of transfer drive layer is J 'i:
Wherein the inflating medium blocking radius under the time step on each substratum is rfi:
Solution blocking layer injectivity index before and after inflating medium injection remains unchanged:
In formula, J 'iFor the injectivity index of transfer drive layer after injection inflating medium, m3/(h·MPa)；JjFor the suction before and after solution blocking layer measure
Aqua index, m3/(h·MPa)；RRF1For inflating medium residual resistance factor；rfiFor the inflating medium blocking radius of transfer drive layer i, m；φi
For the porosity of transfer drive layer i.
5. according to the method described in claim 3, wherein, after completing the inflating medium injection process, outgassing is injected into stratum
Agent solution, during the note bubble release agent, under first time step, the bubble release agent is described according to having infused in splitting point for each layer
Each layer injectivity index after inflating medium split point:
In formula: v2It (z) is the discharge capacity of z-th of slug bubble release agent, m3/h；Q2iFor the bubble release agent injection rate of transfer drive layer i, m3；Q2jFor solution
The bubble release agent injection rate of blocking layer j, m3；
Then calculate each layer injectivity index after first time step:
In formula: θ is bubble release agent acidizing degree；RRF is foam residual resistance factor,
It is wherein reacted due to the inflating medium with the bubble release agent, generates CO2Foam system, by transfer drive layer under a time step
On foam blocking radius reconciliation blocking layer plug removal radius are as follows:
In formula: r 'fiFor the foam blocking radius of transfer drive layer i, m；rsjFor the plug removal radius for solving blocking layer j, m.
6. according to the method described in claim 3, in the future time step of first time step, the bubble release agent carries out dosage
Timesharing is split, split point according to each layer injectivity index after the variation of a upper time step, after sometime walking, when the tune
Total dosage that the bubble release agent dosage in layer is greater than inflating medium is driven, i.e.,When, the suction of the transfer drive layer reconciliation blocking layer
Aqua index computation model are as follows:
The injectivity index calculation formula in the transfer drive layer changes at this time, and the acid of bubble release agent also occurs in transfer drive layer at this time
Change effect, transfer drive layer foam blocking radius and bubble release agent acidizing radius are as follows:
7. according to the method described in claim 1, wherein, after slug recycles, injectivity index coefficient of variation computation model are as follows:
In formula
In formula,For the mean water absorption index on stratum after transfer drive, m3/(h·MPa)；VJFor the injectivity index coefficient of variation.
8. according to the method described in claim 1, wherein, in step (3), being established according to pressure balance principle and seepage theory
Calculation of pressure model in work progress:
Pwht=Pft+ΔP+Pr-Pht (20)
Wherein, PwhtFor medicament well intake pressure, MPa；PhtFor the head of liquid of medicament in the wellbore, MPa；PftExist for medicament
Frictional resistance in pit shaft, MPa；Δ P is displacement pressure difference, MPa；PrFor current strata pressure, MPa.
9. the method stated according to claim 1, wherein in step (4), described solve includes chromosome coding, ideal adaptation
Degree evaluation, selection duplication operation, crossing operation and mutation operator.
10. application of the method described in any one of claims 1 to 9 in reservoir waterflooding.
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