Chemical flooding method for balanced displacement of heterogeneous oil reservoir

Description

TECHNICAL FIELD

The invention relates to a chemical flooding method for balanced displacement of heterogeneous oil reservoir, which belongs to the technical field of oil and gas field development.

TECHNICAL BACKGROUND

At present, there are many problems in the development process of many oilfields, such as large well spacing, multiple layers, strong reservoir heterogeneity, poor injection-production corresponding ratio of chemical flooding, and easy channeling of injected fluid, which make it difficult to achieve balanced displacement.

Chemical flooding is an important method to enhance oil recovery in high water cut oilfields. By injecting chemical agents into the formation, it can effectively reduce water-oil mobility ratio and oil-water interfacial tension to achieve the effect of reducing water production and increasing oil production.

A large number of chemical flooding oilfield practices show that the selection of injection and production well location and fluid quantity, chemical agent type, the ratio of different chemical agent concentration and injection slug volume have a great influence on the development effect. However, there is no perfect parameter design optimization method at present, which greatly affects the development effect and application of chemical flooding.

At present, balanced oil displacement is generally achieved through well position adjustment of injection and production wells or polymer flooding in oilfield development. The method of well location adjustment is generally based on reservoir characteristics and parameters. Although it can obtain better development effect, it is difficult to achieve the optimal development effect. The viscosity and sweep volume of injected water can be increased by polymer injection. However, it does not consider the realization of differentiated injection and production based on the geological characteristics of different regions of the reservoir.

For this reason, the invention proposes a chemical flooding method for balanced displacement of heterogeneous oil reservoir. It can effectively improve the injection-production corresponding ratio of chemical flooding to realize balanced displacement, and provide technical support for greatly improving the development effect of chemical flooding.

Invention Content

Aiming at the deficiency of the existing technology, the invention proposes a chemical flooding method for balanced displacement of heterogeneous oil reservoir, which can provide technical support for oilfields to reduce water production and increase oil production and improve the development effect of chemical flooding.

Terms Explanation:

1, Core flooding experiment: using sand filling pipe, constant thermostat container, flow pump and other experimental devices to carry out water injection drive crude oil experiments.

2, Permeability: most pores in the reservoir are interconnected. Fluid can flow in pores under a certain pressure difference. This property of rock is called permeability, and the unit is generally 10⁻³μm².

3, Effective thickness: the thickness of the part of the reservoir with industrial oil production capacity, that is, the thickness of the reservoir with movable oil.

4, Degree of reserve recovery: Degree of reserve recovery is known as oil recovery factor, which refers to the percentage of cumulative oil production in geological reserves from the beginning of development to the present.

5, Remaining geological reserves: remaining oil and gas geological reserves in underground reservoir except for those developed and produced.

6, Comprehensive evaluation index: An index relates to the permeability, effective thickness, oil recovery factor and remaining geological reserves of the reservoir, which is used to comprehensively reflect the physical properties of a single layer.

7, Well location: the positions of the center position of the rotary table of the surface oil drilling rig, including longitude and latitude.

The technical Scheme of the Invention:

A chemical flooding method for balanced displacement of heterogeneous oil reservoir, including the following steps:

(1) Determination of median size and elastic modulus of viscoelastic particles

The median particle size and elastic modulus of viscoelastic particles are matched with reservoir permeability. Through the known reservoir permeability, the median size and elastic modulus matching the reservoir permeability characteristics can be calculated. Then the viscoelastic particles whose particle size median and elastic modulus meet the calculation results are determined for subsequent chemical flooding.

(2) Optimization of concentration ratio of three chemical agents

The optimal concentration ratio of polymer, surfactant and viscoelastic particles is calculated according to the chemical agent concentration corresponding to the maximum oil increment per ton of agent.

(3) Combination of development layers

The physical parameters of each layer passed by injection well are counted, including permeability, effective thickness, oil recovery factor and remaining geological reserves. The weight of each physical parameter is determined according to the entropy weight algorithm, and the comprehensive evaluation index of each layer is calculated.

The cluster analysis method based on the center of gravity is used to merge the layers, and all the layers are combined into two layers.

(4) Determination of sectional slug volume ratio of chemical flooding (5) Optimization of well location, injection rate and production rate and chemical amount for single well (6) Determination of volume and concentration of sectional slug

According to the optimized step (1) of the invention, the steps of determining the median size and elastic modulus of viscoelastic particles is:

According to the average permeability of the reservoir provided by the oilfield, the median size and elastic modulus of viscoelastic particles matched the target reservoir are calculated based on the matching relationship model between the median particle size and elastic modulus of viscoelastic particles and the average permeability of the reservoir. The calculation formulas are shown in formulas (I) and (II):

d
=−49.8Ln(k)+513.6 (I)

E_m=0.004(k)^1.03−1.241 (II)

According to the optimized step (2) of the invention, the steps of optimizing concentration ratio of three chemical agents is:

{circle around (1)} Based on the core flooding experiment, the concentrations of polymer, surfactant and viscoelastic particles are adjusted respectively under the condition of ensuring the total concentration of chemical agents constant, and no less than 15 groups of core flooding experiments are carried out. The injection volume and cumulative oil production of chemical agents in each group of core flooding experiments are counted, and the oil increment per ton of agent is calculated, as shown in formula (III):

$\begin{matrix} R_{t} = \frac{Q_{o} - Q_{oi}}{(w_{p} + w_{s} + w_{g}) V} & (III) \end{matrix}$

Where R_tis the oil increment per ton of agent, m³/t; Q_ois the cumulative oil production of chemical flooding, 10⁻⁶m³; Q_oiis the cumulative oil production of water flooding, 10⁻⁶m³; w_pis the concentration of polymer, kg/m³; w_gis the concentration of surfactant, kg/m³; w_gis the concentration of viscoelastic particles, kg/m³; V is the injection volume of chemical agent, 10⁻⁶m³.

{circle around (2)} The optimal concentration ratio of polymer, surfactant and viscoelastic particles is calculated as w_p: w_s: w_gaccording to the injection concentration of agent used in the experiment corresponding to the maximum oil increment per ton of agent.

According to the optimized step (3) of the invention, the cluster analysis method based on the gravity center method is adopted for layer combination includes:

First, the Euclidean distance between the layers is calculated and the two layers with the shortest Euclidean distance are merged into a new layer. Then, the Euclidean distance between the new layer and other layers is calculate. repeat this process, and finally combine all layers into two layers. By repeating this process, all layers are finally combined into two layers.

According to the optimized step (4) of the invention, the volume ratio of chemical flooding sectional slug is determined. The specific steps include:

{circle around (1)} The reservoir model with a well group composed of the two layers was established to conduct numerical simulation of two-slug chemical flooding. And the recovery factors with different permeability ratio and thickness ratios of high and low permeability layers are calculated to determine the optimal sectional slug volume ratios of chemical flooding.

{circle around (2)} The horizontal axis was taken as the product of the thickness ratio of the high and low permeability layers and the permeability ratio of step {circle around (1)}, and the vertical axis was taken as the optimal sectional slug volume ratios of chemical flooding. A scatter plot was drawn, and the standard plate of the sectional slug volume ratios of chemical flooding was obtained through nonlinear regression.

{circle around (3)} The product of thickness ratio of high and low permeability layers and permeability ratio of each well is determined, and the optimal sectional slug volume ratios of chemical flooding d₁:d₂are determined with the standard plate of the sectional slug volume ratios. The sectional slug volume ratios of chemical flooding d₁:d₂refers to the ratio of the volume of chemical flooding slug 1 to the volume of chemical flooding slug 2 which adjacent to the chemical flooding slug 1.

According to the optimized invention, the specific realization steps of step {circle around (1)} include:

Firstly, a single well group reservoir model is intercepted from the target reservoir model, and models composed of the two layers with different permeability ratio and different thickness ratios of high and low permeability layers are established.

Then, for a certain model of permeability ratio and thickness ratio of high and low permeability layers, under the condition of the same total volume of chemical agents, the chemical flooding numerical simulator is used to calculate the recovery factors of different sectional slug volume ratios.

Finally, a scatter plot was drawn with the sectional slug volume ratio as the horizontal axis and the recovery factor as the vertical axis. The sectional slug volume ratios corresponding to the maximum recovery factor was obtained by fitting, that is, the optimal sectional slug volume ratio under the specified condition of the permeability ratio and the thickness ratio of the high and low permeability layers.

According to the optimized step (5) of the invention, the location of wells, the amount of injection, production and chemical agents are optimized, including the following steps

Considering remaining oil saturation variation coefficient which is the characterization of chemical flooding of equilibrium degree, the oil increase effect of the chemical flooding and chemical agents cost, the objective function of the injection-production optimization coordination chemical flooding achieve equilibrium displacement such as equation (IV) is determined as below:

$\begin{matrix} Obj = \frac{(1 - S_{or} - {\overline{S}}_{o} (L, q_{i}, q_{p})}{(\begin{matrix} V_{r} (S_{o} (L, q_{i}, q_{p})) \\ (\begin{matrix} P_{P} \frac{w_{p}}{w_{p} + w_{s} + w_{g}} + \\ P_{S} \frac{w_{s}}{w_{p} + w_{s} + w_{g}} + \\ P_{g} \frac{w_{g}}{w_{p} + w_{s} + w_{g}} \end{matrix}) \end{matrix} \sum_{i = 1}^{n} C_{Tc, i} V_{T, i}} & (IV) \end{matrix}$

In the equation (IV), Obj is the objective function of the injection-production optimization coordination chemical flooding achieve equilibrium displacement; L is the location coordinates of injectors and producers; q_iis injection rate of each injector; q_pis production rate of each producer; S_oris remaining oil saturation, fraction; S_o(L,q_iq_p) is the average remaining oil saturation, fraction; S_o(L,q_i,q_p) is remaining oil saturation, fraction; V_r(S_o) is the remaining oil saturation variation coefficient, fraction; C_Tc,iis the total concentration of chemical agents injected into injector i, kg/m³; V_T,iis the total volume of chemical agents injected into injector i, m³; P_pis the price of polymer, yuan/kg; P_Sis the price of surfactant, yuan/m³; P_gis the price of viscoelastic particle, yuan/kg; L,q_i,q_pare input into the chemical flooding numerical simulator to obtain S_o(L,q_i,q_p).

With the maximum of Obj is the goal, the location coordinates of injectors and producers L, total chemical agents concentration injected into injector i C_Tc,i, chemical agents total injection volume of injector i V_T,i, liquid production rate of producers qⁱand liquid injection rate of injectors q_pare adjustable variables. When the well location coordinates of injectors and producers, liquid production rate of producers and liquid injection rate of injectors change, the average variation coefficient of residual oil saturation and remaining oil saturation calculated by the chemical flooding numerical simulation are also change, which affects the value of the objective function. Chemical flooding numerical simulator is used to calculate Obj with combination of different value of adjustable variables, and the corresponding adjustable variable is the optimal value of each adjustable variable when Obj achieves the maximum.

According to the optimized step (6) of the invention, the volume and concentration of the sectional slug for each well are determined. The specific realization steps include:

According to the total chemical agents concentration of injector i C_Tc,i, chemical agents total injection volume of injector i V_T,i, optimal concentration ratio of polymers, surfactants and viscoelastic particles w_p: w_s: w_gand optimal sectional slug volume ratios of chemical flooding d₁:d₂, injection concentration of each chemical agent and sectional slug volume of chemical flooding are calculated. And the chemical concentration injected into injector i C_l,iis shown in equation (V):

$\begin{matrix} C_{l, i} = C_{Tc, i} \frac{w_{l}}{\sum w_{l}} & (V) \end{matrix}$

In equation (V), l ∈{p,s,g}, w_iis the optimum concentration of the chemical agents, p refer to polymer, s refer to surfactant, g refer to viscoelastic particle;

The volume of jth chemical flooding slug injected into injector i is shown in the equation (VI):

$\begin{matrix} V_{T, i, j} = V_{T, i} \frac{d_{j}}{\sum d_{j}} & (VI) \end{matrix}$

In equation (VI), the value of j is 1 or 2, when j is 1, equation (VI) is the volume of first chemical flooding slug injected into injector. when j is 2, equation (VI) is the volume of second chemical flooding slug injected into injector.

The beneficial Effects of the Invention are as Follows:

- 1. By screening the viscoelastic particles that match the reservoir permeability, the plugging effect of viscoelastic particles in the formation can be maximized and the degree of reserve recovery can be improved effectively.
- 2. By optimizing the concentration ratio of the three chemical agents, the synergistic effect between the chemical agents can be effectively improved, and the degree of reserve recovery improved by each chemical agent can be maximized.
- 3. Through the combination of development layer series, the layers with similar characteristics are combined and the same injection and production is adopted, so that the workload of subsequent optimization can be greatly reduced while the development effect can be approximately guaranteed.
- 4. By optimizing the location of wells, the amount of injection and production, and the amount of chemical agents used, the interaction between the variables can be reduced. And the variables adapted to the current geological characteristics can be obtained which maximize the economic and technological benefits of development.

ATTACHED DRAWINGS

FIG. 1 is schematic diagram of the process of the method for realizing balanced displacement of crude oil by injection and production optimization coordinated chemical flooding;

FIG. 2 is schematic diagram of optimization results of slug volume ratios;

FIG. 3 is schematic diagram of well location;

FIG. 4 is schematic diagram of oil recovery factor curve.

SPECIFIC IMPLEMENTATION

The invention is further limited by the following illustration and implementation example, but not limited to this.

EXAMPLE 1

(1) Determination of Median Size and Elastic Modulus of Viscoelastic Particles

(2) Optimization of Concentration Ratio of Three Chemical Agents

(3) Combination of Development Layers

The cluster analysis method based on the center of gravity is used to merge the layers, and all the layers are combined into two layers.

(4) Determination of Sectional Slug Volume Ratio of Chemical Flooding

(5) Optimization of Well Location, Injection Rate and Production Rate and Chemical Amount for Single Well

(6) Determination of Volume and Concentration of Sectional Slug

EXAMPLE 2

According to the method for realizing balanced displacement of crude oil by injection and production optimization coordinated chemical flooding described in Example 1, the difference is as follows:

The determination of median size and elastic modulus of viscoelastic particles in step (1) includes the following steps:

The average permeability of a reservoir is 856×10⁻³μm². The median size and elastic modulus of viscoelastic particles matched the target reservoir are calculated based on the matching relationship model between the median particle size and elastic modulus of viscoelastic particles and the average permeability of the reservoir. The calculation formulas are shown in formulas (I) and (II):

d
=−49.8Ln(k)+513.6 (I)

E
_m=0.004(k)^1.03−1.241 (II)

Where k is the average permeability of the reservoir, 10⁻³μm²; d is the median size of viscoelastic particles matched the target reservoir, μm; E_mis the elastic modulus of viscoelastic particles matched to the target reservoir, Pa; Ln( )is a logarithmic function. According to formula (I) and (II), the median size of viscoelastic particles matching the permeability of the reservoir is calculated as 177.34 μm, and the elastic modulus is 2.95Pa.

The optimization of concentration ratio of three chemical agents in step (2) includes the following steps:

- {circle around (1)} Based on the core flooding experiment, the concentrations of polymer, surfactant and viscoelastic particles are adjusted respectively under the condition of ensuring the total concentration of chemical agents constant, and 16 groups of core flooding experiments are carried out. The injection volume and cumulative oil production of chemical agents in each group of core flooding experiments are counted, and the oil increment per ton of agent is calculated, as shown in formula (III):

$\begin{matrix} R_{t} = \frac{Q_{o} - Q_{oi}}{(w_{p} + w_{s} + w_{g}) V} & (III) \end{matrix}$

In this example, the total chemical concentration is 4 kg/m³and the injection volume is 240×10⁻⁶m³. The maximum oil increment per ton of agent is 51.11m³/t, and the corresponding water flooding oil production is 37.8×10⁻⁶m³. The cumulative oil production of chemical flooding is 74.6×10⁻⁶m³, the oil increment is 36.8×10⁻⁶m³, and the concentration ratio of polymer, surfactant and viscoelastic particles is 1:2:1.

The combination of development layers in step (3) includes the following steps:

The permeability, effective thickness, degree of reserve recovery and remaining geological reserves of each layer in a well group of a reservoir are shown in table 1.

TABLE 1

Degree
Remaining

Effective
of reserve
geological
Comprehensive

Permeability/
thickness/
recovery/
reserves/
evaluation

Layer
(10⁻³μm²)
m
%
(10⁴m³)
index

1
72.9
1.0245
3.96
3.17
0.01057

2
411.9
1.0279
7.43
4.48
0.02670

3
1008.1
1.0269
17.28
6.17
0.05120

4
774.8
1.0269
33.01
6.51
0.05396

5
927.6
1.0273
48.05
4.78
0.05047

6
1489.5
1.0270
54.90
3.18
0.05269

7
917
1.1609
45.90
3.32
0.06211

8
1734.3
1.4937
36.74
5.40
0.14263

9
1667.3
1.4881
40.71
3.84
0.13184

10
848.6
1.4857
57.57
2.41
0.11262

11
166.6
1.4856
61.63
1.50
0.09568

12
669.7
1.4762
57.02
2.27
0.10672

13
442.6
1.4765
59.15
2.19
0.10282

Firstly, the weights of permeability, effective thickness, recovery degree and residual geological reserves can be calculated as 0.1858, 0.48, 0.1462 and 0.1879 respectively according to the entropy weight algorithm. Then, the comprehensive evaluation indexes of each layer can be calculated based on it, as shown in Table 1.

The cluster analysis method based on the center of gravity is used to merge the layers, and all the layers are combined into two layers. First, the Euclidean distance between the layers is calculated and the two layers with the shortest Euclidean distance are merged into a new layer. Then, the Euclidean distance between the new layer and other layers is calculate. repeat this process, and finally combine all layers into two layers. By repeating this process, all layers are finally combined into two layers. Dividing the reservoir into two layers can effectively reflect the rhythm and vertical heterogeneity, and the permeability gradient and thickness of each layer are in the range of multi-slug chemical flooding. Therefore, the reservoir is divided into two layers. The first layer includes 1-7 layers, and the second layer includes 8-13.

The determination of sectional slug volume ratio of chemical flooding in step (4) includes the following steps:

In the Embodiment, reservoir simulation models with a single well group composed of the two layers is established to carry out numerical simulation of chemical flooding. The permeability ratio of two layers is 3, 5 and 7 respectively, and the thickness ratio of the high and low permeability layers is 0.1, 0.4 and 0.6. Chemical flooding is divided into two stage according to the different chemical slug concentration. Under the condition of same injected chemical agents volume, changing the size of the two slug, numerical simulation models with sectional slug volume ratios of 0.17, 0.27, 0.4, 0.75, 1.33, 2.5 are established to calculate the recovery factor and determine the optimal sectional slug volume ratio.

The product of the thickness ratio of the high and low permeability layers and the permeability ratio was found to have a quadratic polynomial relationship with the optimal sectional slug volume ratio in chemical flooding. The least square method was used for regression, and the quadratic polynomial coefficient was calculated. The curve of the quadratic polynomial obtained was plotted in the coordinate axis, which is the standard plate of the sectional slug volume ratios of chemical flooding.

According to the calculated layer combination results, the effective thickness and permeability of each layer in each injector are counted, and the product of the thickness ratio of high and low permeability layers and the permeability ratio of each well is calculated. The designed chemical agent concentration is 4kg/m³. And the volume ratio of slug 1 to slug 2 obtained according to the diagram is shown in Table 2.

TABLE 2

Effective
Effective

Permeabil-
Permeabil-
thickness
thickness

ity of high
ity of low
of high
of low
Volume

permeabil-
permeabil-
permeabil-
permeabil-
ratio of

ity layer/
ity layer/
ity layer/
ity layer/
slug 1 to

Injector
(10⁻³μm²)
(10⁻³μm²)
m
m
slug 2

C5
1752.3
854.6
9.6
8.5
1.41:1

C11
1103.2
536.4
7.6
7.6
1.37:1

C15
1732.4
962.5
8.2
8.6
1.30:1

C9
1752.3
1057.5
9.4
7.9
1.35:1

C14
743.6
429.5
7.3
9.2
1.22:1

C19
985.5
448.9
8.4
8.2
1.40:1

D16
1459.2
1120.3
9.6
8.6
1.24:1

C17
1834.5
1347.7
8.9
8.4
1.24:1

C21
1128.7
524.6
8.5
7.2
1.45:1

The optimization of well location, injection rate and production rate and chemical amount for single well in step (5) includes the following steps:

In the equation (IV), Obj is the objective function of the injection-production optimization coordination chemical flooding achieve equilibrium displacement; L is the location coordinates of injectors and producers; qⁱis injection rate of each injector; q_pis production rate of each producer; S_oris remaining oil saturation, fraction; S_o(L,q_i,q_p) is the average remaining oil saturation, fraction; S_o(L,q_i,q_p) is remaining oil saturation, fraction; V_r(S_o) is the remaining oil saturation variation coefficient, fraction; C_Tc,iis the total concentration of chemical agents injected into injector i, kg/m³; V_T,iis the total volume of chemical agents injected into injector i, m³; P_pis the price of polymer, yuan/kg; P_Sis the price of surfactant, yuan/m³; P_gis the price of viscoelastic particle, yuan/kg; L,q_i,q_pare input into the chemical flooding numerical simulator to obtain S_o(L,q_i,q_p).

With the maximum of Obj is the goal, the location coordinates of injectors and producers L, total chemical agents concentration injected into injector i C_Tc,i, chemical agents total injection volume of injector i V_T,i, liquid production rate of producers q_iand liquid injection rate of injectors q_pare adjustable variables. When the well location coordinates of injectors and producers, liquid production rate of producers and liquid injection rate of injectors change, the average variation coefficient of residual oil saturation and remaining oil saturation calculated by the chemical flooding numerical simulation are also change, which affects the value of the objective function. Chemical flooding numerical simulator is used to calculate Obj with combination of different value of adjustable variables, and the corresponding adjustable variable is the optimal value of each adjustable variable when Obj achieves the maximum.

In the Embodiment, remaining oil saturation, the average remaining oil saturation and the remaining oil saturation variation coefficient of the reservoir are 0.25, 0.32 and 0.34, respectively.

And the price of polymer, the price of surfactant and the price of viscoelastic particle are 12 yuan/kg, 10 yuan/m³and 15 yuan/m³, respectively. And the value of optimal adjustable variables are shown in Table 3 and Table 4. Table 3 shows the production parameters optimization results of each producer. And Table 4 shows the injection parameters optimization results of each injector. The well location shows in the FIG. 3.

TABLE 3

Optimal production

Optimal production

Producer
rate/(m³/d)
Producer
rate/(m³/d)

C29
135.51
D13
164.79

C6
219.64
C24
257.10

C12
204.20
C18
227.72

C16
114.30
C32
148.85

C4
214.55
D15
62.92

C10
372.34
D19
118.80

C30
338.05
C31
148.15

C28
180.43
C23
112.65

TABLE 4

Optimal total

Volume of
Volume of

Optimal total
chemical agents
Optimal

Concentration
chemical
chemical

chemical agents
injection
injection
Concentration
Concentration
of viscoelastic
flooding
flooding

concentration/
volume/
rate/
of polymer/
of surfactant/
particle/
slug
slug

Injector
(kg/m³)
(m³)
(m³/d)
(kg/m³)
(kg/m³)
(kg/m³)
1/m³
2/m³

C5
3.6
1159.27
480
0.90
1.80
0.90
678.25
481.02

C11
4.6
918.44
410
1.15
2.30
1.15
530.91
387.53

C15
3.2
1011.96
450
0.80
1.60
0.80
571.98
439.98

C9
4.8
1217.28
400
1.20
2.40
1.20
699.29
517.99

C14
3.4
633.28
220
0.85
1.70
0.85
348.02
285.26

C19
4.6
853.28
240
1.15
2.30
1.15
497.75
355.53

D16
4.8
986.26
230
1.20
2.40
1.20
545.97
440.29

C17
3.8
803.88
260
0.95
1.90
0.95
445.01
358.88

C21
4.2
851.35
330
1.05
2.10
1.05
503.86
347.49

The determination of volume and concentration of sectional slug in step (6) includes the following steps:

$\begin{matrix} C_{l, i} = C_{Tc, i} \frac{w_{l}}{\sum w_{l}} & (V) \end{matrix}$

In equation (V), l 531 {p, s, g}, w_lis the optimum concentration of the chemical agents, p refer to polymer, s refer to surfactant, g refer to viscoelastic particle;

The volume of jth chemical flooding slug injected into injector i is shown in the equation (VI):

$\begin{matrix} V_{T, i, j} = V_{T, i} \frac{d_{j}}{\sum d_{j}} & (VI) \end{matrix}$

The polymer concentration, surfactant concentration, viscoelastic particle concentration, volume of first chemical flooding slug V_T,i,land volume of second chemical flooding slug V_T,i,2of each injector calculated by equation (VI) are shown in the FIG. 4.

Based on the above results, it was substituted into the numerical simulation calculation, and the recovery factor curve obtained is shown in FIG. 4.

Claims

1. A chemical flooding method for balanced displacement of heterogeneous oil reservoir, including the following steps: (1) determining median size and elastic modulus of viscoelastic particles;(2) optimizing concentration ratio of three chemical agents;optimal concentration ratio of polymer, surfactant and viscoelastic particles is calculated according to chemical agent concentration corresponding to maximum oil increment per ton of agent;(3) combining development layers;(4) determining sectional slug volume ratio of chemical flooding;(5) optimizing well location, injection rate and production rate and chemical amount for single well; and(6) determining volume and concentration of sectional slug.
2. The chemical flooding method for balanced displacement of heterogeneous oil reservoir according to claim 1, wherein combination of development layers in Step (3) refer to: physical parameters of each layer passed by injection well are counted, including permeability, effective thickness, oil recovery factor and remaining geological reserves; weight of each physical parameter is determined according to the entropy weight algorithm, and the comprehensive evaluation index of each layer is calculated;cluster analysis method based on the center of gravity is used to merge the layers, and all the layers are combined into two layers.
3. The chemical flooding method for balanced displacement of heterogeneous oil reservoir according to claim 1, wherein the determination of median size and elastic modulus of viscoelastic particles in Step (1) refer to: according to the average permeability of the reservoir provided by the oilfield, the median size and elastic modulus of viscoelastic particles matched the target reservoir are calculated based on the matching relationship model between the median particle size and elastic modulus of viscoelastic particles and the average permeability of the reservoir; the calculation formulas are shown in formulas (I) and (II): d=−49.8Ln(k)+513.6 (I)Em=0.004(k)1.03−1.241 (II)wherein k is the average permeability of the reservoir, 10−3μm2; d is the median size of viscoelastic particles matched the target reservoir, μm; Em is the elastic modulus of viscoelastic particles matched to the target reservoir, Pa; Ln( )is a logarithmic function.
4. The chemical flooding method for balanced displacement of heterogeneous oil reservoir according to claim 1, wherein optimization of concentration ratio of three chemical agents in Step (2) refer to: i) he concentrations of polymer, surfactant and viscoelastic particles are adjusted respectively under the condition of ensuring the total concentration of chemical agents constant, and no less than 15 groups of core flooding experiments are carried out; the injection volume and cumulative oil production of chemical agents in each group of core flooding experiments are counted, and the oil increment per ton of agent is calculated, as shown in formula (III):
5. The chemical flooding method for balanced displacement of heterogeneous oil reservoir according to claim 2, wherein the cluster analysis method based on the gravity center method is adopted for layer combination includes the following steps: first, the Euclidean distance between the layers is calculated and the two layers with the shortest Euclidean distance are merged into a new layer; then, the Euclidean distance between the new layer and other layers is calculate. repeat this process, and finally combine all layers into two layers; by repeating this process, all layers are finally combined into two layers.
6. The chemical flooding method for balanced displacement of heterogeneous oil reservoir according to claim 1, wherein the determination of sectional slug volume ratio of chemical flooding in Step (4) refer to: i) the reservoir model with a well group composed of the two layers was established to conduct numerical simulation of two-slug chemical flooding; and the recovery factors with different permeability ratio and thickness ratios of high and low permeability layers are calculated to determine the optimal sectional slug volume ratios of chemical flooding;ii) the horizontal axis was taken as the product of the thickness ratio of the high and low permeability layers and the permeability ratio of step i), and the vertical axis was taken as the optimal sectional slug volume ratios of chemical flooding; a scatter plot was drawn, and the standard plate of the sectional slug volume ratios of chemical flooding was obtained through nonlinear regression;iii) the product of thickness ratio of high and low permeability layers and permeability ratio of each well is determined, and the optimal sectional slug volume ratios of chemical flooding d1:d2 are determined with the standard plate of the sectional slug volume ratios; the sectional slug volume ratios of chemical flooding d1:d2 refers to the ratio of the volume of chemical flooding slug 1 to the volume of chemical flooding slug 2 which adjacent to the chemical flooding slug 1.
7. The chemical flooding method for balanced displacement of heterogeneous oil reservoir according to claim 6, wherein the concrete implementation steps of step i) include refer to: firstly, a single well group reservoir model is intercepted from the target reservoir model, and models composed of the two layers with different permeability ratio and different thickness ratios of high and low permeability layers are established;then, for a certain model of permeability ratio and thickness ratio of high and low permeability layers, under the condition of the same total volume of chemical agents, the chemical flooding numerical simulator is used to calculate the recovery factors of different sectional slug volume ratios;finally, a scatter plot was drawn with the sectional slug volume ratio as the horizontal axis and the recovery factor as the vertical axis; the sectional slug volume ratios corresponding to the maximum recovery factor was obtained by fitting, that is, the optimal sectional slug volume ratio under the specified condition of the permeability ratio and the thickness ratio of the high and low permeability layers.
8. The chemical flooding method for balanced displacement of heterogeneous oil reservoir according to claim 1, wherein the optimization of well location, injection rate and production rate and chemical amount for single well in Step (5) refer to: considering remaining oil saturation variation coefficient which is the characterization of chemical flooding of equilibrium degree, the oil increase effect of the chemical flooding and chemical agents cost, the objective function of the injection-production optimization coordination chemical flooding achieve equilibrium displacement such as equation (IV) is determined as below:
9. The chemical flooding method for balanced displacement of heterogeneous oil reservoir according to claim 1, wherein the determination of volume and concentration of sectional slug in Step (6) refer to: according to the total chemical agents concentration of injector i CTc,i, chemical agents total injection volume of injector i VT,i, optimal concentration ratio of polymers, surfactants and viscoelastic particles wp: ws: wg and optimal sectional slug volume ratios of chemical flooding d1:d2, injection concentration of each chemical agent and sectional slug volume of chemical flooding are calculated; and the chemical concentration injected into injector i Cl,i is shown in equation (V):
10. The chemical flooding method for balanced displacement of heterogeneous oil reservoir according to claim 4, its characteristic is that there is no less than 15 groups of core flooding experiments are carried out.

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Number	Date	Country	Kind
202110318238.9	Mar 2021	CN	national

Chemical flooding method for balanced displacement of heterogeneous oil reservoir

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