CN103244087A - Profile control and water plugging well selection decision-making method for low-permeability reservoirs - Google Patents

Abstract

The invention provides a profile control and water plugging well selection decision-making method for low-permeability reservoirs. The method comprises calculating a fourth decision-making factor CI reflecting the injectivity of a plugging agent, a first anisotropic decision-making factor Pa1 in representation layers, a second anisotropic decision-making factor Pa2 among the representation layers, and a third anisotropic decision-making factor Pa3 on the representation plane respectively; establishing a profile control and water plugging decision-making factor RMF; and using the profile control and water plugging decision-making factor RMF for profile control and water plugging well selection decision-making; and calculating an accumulated oil increment QT of the profile control and water plugging measure, which represents the profile control and water plugging measure effect, by using the profile control and water plugging decision-making factor RMF. By means of the method, the problems of instable calculation results and poor effect predictive when a pressure index (PI) decision is applied to low-permeability reservoirs, and the scientific profile control and water plugging decision for low-permeability reservoirs is implemented.

Description

Profile control, water plugging and well selection decision method for low-permeability oil reservoir

Technical Field

The invention relates to the field of profile control and water shutoff well selection decision-making in oil reservoir development and adjustment, in particular to a profile control and water shutoff well selection decision-making method for a low-permeability oil reservoir.

Background

For the development of oil fields by water injection, the underground oil-water distribution tends to be complex gradually, the water content level and the utilization degree in layers, interlaminations and planes are more and more different, and the heterogeneity is more and more serious, so that the injected water is suddenly fed and cross-flowed, the oil displacement efficiency is reduced, the early flooding of the oil well is caused, and the development effect of the oil field is influenced. Therefore, the water channeling direction between the water producing layer and the interlayer and the well group flooding condition are determined in time, and the adoption of the targeted profile control and water shutoff measures is particularly important for the efficient and economic development of the oil reservoir.

In the process of profile control and water shutoff of a water injection block of a medium-high permeability oil field at present, a PI (Pressure Index) decision method is widely applied due to simple and convenient technology. However, the PI decision-making method has poor adaptability when guiding the profile control and water shutoff well selection of the low-permeability oilfield, and the specific expression is that the calculated PI decision-making factor is unstable, and the operation of the profile control and water shutoff measures on site cannot be accurately guided; the PI decision factor has low correlation with accumulated oil and accumulated precipitation of an affected well group, and has weak prediction effect on the profile control and water plugging effect of the well group.

For this reason, the PI decision method only describes the basis for the implementation of profile control and water shutoff: the injectivity can not depict the key of success or failure of profile control and water shutoff implementation: reservoir heterogeneity. In consideration of the fundamental defect of the PI decision-making technology, on the basis of low-permeability reservoir seepage mechanism and geological research, dynamic and static data are combined, heterogeneous characteristics, development characteristics, injectability of plugging agents and other factors of the low-permeability reservoir are comprehensively considered, and the establishment of a brand-new profile control and water plugging well selection decision-making method has important practical significance for guiding field plugging control operation of the low-permeability oil field.

Disclosure of Invention

The embodiment of the invention mainly aims to provide a low-permeability oil reservoir profile control and water plugging well selection decision-making method, and solves the problems that when the existing PI decision-making method is applied to a low-permeability oil field, the decision-making factor is unstable in calculation, the applicability is poor and the plugging effect prediction capability is low due to the fact that reservoir heterogeneity cannot be reflected.

In order to achieve the above object, an embodiment of the present invention provides a method for making a decision for profile control, water shutoff and well selection of a low permeability reservoir, including:

respectively calculating a fourth decision factor CI reflecting the injectability of the plugging agent, a first decision factor Pa1 representing the intralayer heterogeneity, a second decision factor Pa2 representing the interlaminar heterogeneity and a third decision factor Pa3 representing the planar heterogeneity;

establishing a blocking regulation decision factor RMF according to the fourth decision factor CI, the first decision factor Pa1, the second decision factor Pa2 and the third decision factor Pa 3;

applying the plugging adjustment decision factor RMF to carry out plugging adjustment and well selection decisions;

calculating the accumulative oil increment Q of the blockage regulating measure for indicating the effect of the blockage regulating measure by utilizing the blockage regulating decision factor RMF_T。

By means of the technical scheme, four decision factors are respectively derived from the angle of dynamic and static combination according to the fluid injectivity and the heterogeneous oil reservoir: the method comprises the steps of reflecting the injectability of a plugging agent, using a fourth decision factor CI to represent the intralayer heterogeneity, using a first decision factor Pa1 to represent the intralayer heterogeneity, using a second decision factor Pa2 to represent the interlaminar heterogeneity, using a third decision factor Pa3 to represent the planar heterogeneity, combining the four decision factors, establishing a plugging regulation decision factor RMF, and using the plugging regulation decision factor RMF to carry out plugging regulation and well selection decisions and measure oil increment prediction. Compared with the prior art, the method solves the problems of unstable calculation result and poor effect predictability when the PI decision is applied to the low-permeability oil reservoir, and realizes the scientific decision for profile control and water shutoff of the low-permeability oil reservoir.

Drawings

In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings required to be used in the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art that other drawings can be obtained according to the drawings without inventive labor.

Fig. 1 is a schematic flow chart of a low permeability reservoir profile control water shutoff well selection decision-making method according to an embodiment of the present invention.

Detailed Description

The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.

Example one

The embodiment provides a decision-making method for profile control, water shutoff and well selection of a low permeability reservoir, as shown in fig. 1, the method comprises the following steps:

step S11, respectively calculating a fourth decision factor CI for representing the injectability of the plugging agent, a first decision factor Pa1 for representing the intralayer heterogeneity, a second decision factor Pa2 for representing the interlaminar heterogeneity and a third decision factor Pa3 for representing the plane heterogeneity;

step S12, establishing a blocking adjustment decision factor RMF according to the fourth decision factor CI, the first decision factor Pa1, the second decision factor Pa2 and the third decision factor Pa 3;

step S13, applying the plugging adjustment decision factor RMF to make plugging adjustment and well selection decisions;

step S14, calculating the accumulative oil increment Q of the blockage regulating measure for indicating the effect of the blockage regulating measure by utilizing the blockage regulating decision factor RMF_T。

In this embodiment, from the perspective of dynamic-static combination, four decision factors are derived for fluid injectability and reservoir heterogeneity: a fourth decision factor CI reflecting the injectability of the plugging agent, a first decision factor Pa1 representing the intralaminar heterogeneity, a second decision factor Pa2 representing the interlaminar heterogeneity and a third decision factor Pa3 representing the planar heterogeneity, and then the four decision factors are combined to establish a plugging regulation decision factorThe factor RMF is used for carrying out plugging adjustment and well selection decision by applying the plugging adjustment decision factor RMF, and the accumulated oil increment Q of the predicted plugging adjustment measures is calculated_T. Compared with the prior art, the method and the device solve the problems of unstable calculation result and poor effect predictability when the PI decision is applied to the low-permeability reservoir, and realize the scientific decision for profile control and water shutoff of the low-permeability reservoir.

Preferably, in the step S11, the fourth decision factor CI reflecting the injectability of the plugging agent is calculated, which may be specifically divided into the following four processes:

process 1, determining t for each well in a low permeability field in a pressure test curve log_c、t_e、t₁Value and corresponding Δ p_c、Δp_e、Δp₁A value;

in the process, the pressure test curve bi-logarithmic graph refers to a curve of effective time-pressure data obtained by monitoring the pressure of a water injection well or an oil production well under a bi-logarithmic coordinate, the abscissa is ln delta t, and the ordinate is ln delta p;

the effective time-pressure data is time-pressure data which can reflect formation pressure change in the pressure monitoring data and can be used for analysis;

Δ t is the time variation during the pressure test, defined as: Δ t ═ t-t₀L, |; wherein t is the time in the valid time-pressure data; t is t₀Valid time-the moment when the pressure data starts;

Δ p is the pressure change during the pressure test, defined as: Δ p ═ p_t-p_iL, |; wherein p is_tThe pressure value is the corresponding pressure value of the effective time-pressure data at the moment t; p is a radical of_iAs valid time-pressure data t₀The pressure value corresponding to the moment;

t_cfor the end of the well-reservoir control phase, Δ p_cIs t_cCorresponding pressure changes in the valid time-pressure data at the moment;

t_eto effective timeEnd of pressure data, Δ p_eIs t_eCorresponding pressure changes in the valid time-pressure data at the moment;

t₁is t_cTime and t_eA middle time of the time, andΔp₁is t₁The time of day is the corresponding pressure change in the valid time-pressure data.

Process 2, using equation 1, from t_cAnd Δ p_cCalculating a well storage coefficient C:

$C=\frac{Q_{\mathrm{inj}}{t}_c}{\mathrm{\Δ}{p}_c}$ (formula 1)

In formula 1, Q_injThe current daily water injection amount of the water injection well or the current daily liquid production amount of the oil production well.

Procedure 3, using equation 2, based on t, respectively_c、Δp_c、t₁、Δp₁And t_e、Δp_eValue calculation formation permeability k₁、k₂；

(formula 2)

In equation 2, Δ t₁'、Δt_e’、Δp₁'、Δp_e’、Q₁、Q_eIs an intermediate parameter; for the profile control of a water injection well,the method comprises the following steps of weighting and calculating the viscosity of oil and water of a first-line oil production well of a water injection well according to the current water content to obtain the arithmetic average value of the viscosity, wherein the first-line oil production well refers to an oil production well which is closest to the water injection well in the injection and production direction; for the water plugging of the oil production well,

the viscosity is obtained after the oil viscosity and the water viscosity are weighted and calculated according to the current water content; b is a volume coefficient; h is_ewIs the effective thickness; eta is the pressure conduction coefficient; k is a radical of_e2The current reservoir permeability for a water injection well or a production well; r is_eIs the feed radius; p is a radical of_tubIs the tubing pressure; c_tThe compression coefficient is the comprehensive compression coefficient of the crude oil; r is_wIs the wellbore radius;

in this process, r is recommended_eAnd taking half of the distance between injection wells and production wells.

Procedure 4, using equation 3, based on formation permeability k₁、k₂Calculating a fourth decision factor CI:

$\left\{\begin{array}{c}\mathrm{IC}0=\frac{1}{\sqrt{k_1{k}_2}}\\ \mathrm{CI}=C_1\frac{\mathrm{CI}0}{\frac{Q_{\mathrm{inj}}}{h_{\mathrm{ew}}}}\frac{{\stackrel{\‾}{Q}}_{\mathrm{inj}}}{{\stackrel{\‾}{h}}_{\mathrm{ew}}}\end{array}\right.$ (formula 3)

In equation 3, CI0 is the fourth decision factor that is not normalized;

for water injection wells or oil production wells_injAn arithmetic mean of the values;

h for water injection well or oil production well_ewAn arithmetic mean of the values; c₁Is a first normalization coefficient;

the process begins with the formation permeability k₁、k₂Calculating the fourth non-normalized decision factor CI0, using Q to make the calculated CI0 for each well comparable_inj、h_ewModifying and normalizing the CI0 to obtain a fourth decision factor CI reflecting the injectability of the plugging agent; recommending a first normalization factor C₁=0.1, in a specific operation, C₁Other values may be used depending on the actual situation.

Preferably, in the step S11, the first decision factor Pa1 for characterizing the intralevel heterogeneity is calculated, specifically:

the first decision factor Pa1 is calculated using equation 4:

$\mathrm{Pa}1=C_2\frac{Q_w}{\mathrm{\Δ}{{\stackrel{\‾}{f}}_w}^3{h}_{\mathrm{ew}}}$ (formula 4)

In formula 4, C₂Is a second normalization coefficient; for water injection wells, Q_w(ii) an accumulated water injection volume since a bet was placed for the water injection well; for oil wells, Q_wThe accumulated liquid production of the oil production well after betting for the affected water injection well; in the case of a water injection well,

the difference value of the arithmetic mean value of the current water content of the first-line oil production well and the arithmetic mean value of the corresponding water content when the water injection well bets is obtained; in the case of an oil-producing well,

the difference value of the current water content and the corresponding water content when the effective water injection well bets is obtained; recommending a second normalization factor C₂=10, in concrete operation, C₂Other values may be used depending on the actual situation.

Preferably, in the step S11, the calculating a second decision factor Pa2 representing interlayer heterogeneity specifically includes:

using equation 5, a second decision factor Pa2 is calculated:

$\mathrm{Pa}2=\frac{k_{e1}}{k_{e2}}$ (formula 5)

In equation 5, k_e1For reservoir permeability, k, in the case of production of water injection or oil production wells_e1The effective thickness can be obtained by weighted calculation according to the well logging interpretation permeability; k is a radical of_e2The current reservoir permeability for a water injection well or a production well.

In this embodiment, the third decision factor Pa3 representing the planar heterogeneity is considered only during profile control of the water injection well, and the decision factor Pa3 is defaulted to 1 during water shutoff decision of the oil production well.

Preferably, in the step S11, the third decision factor Pa3 for characterizing the planar heterogeneity is calculated, specifically:

for a water plugging decision of the oil production well, determining a third decision factor Pa3= 1;

for a water injection well profile control decision, a third decision factor Pa3 is calculated using equation 6:

$\left\{\begin{array}{c}\mathrm{Pa}{3}^{\′}=\frac{Q_o}{\mathrm{\Δ}{f_w}^3{h}_{\mathrm{eo}}}\\ \mathrm{Pa}3=C_3\{1-\frac{{\left\{\mathrm{Pa}{3}^{\′}\right\}}_{0.85}-{\left\{\mathrm{Pa}{3}^{\′}\right\}}_{0.5}}{{\left\{\mathrm{Pa}{3}^{\′}\right\}}_{0.5}}\}\end{array}\right.$ (formula 6)

In formula 6, Pa 3' is a decision value corresponding to each production well in the first line; q_oThe accumulated oil production of each first-line oil production well after betting for the affected water injection well; Δ f_wThe difference value of the current water content of the first-line oil production well and the corresponding water content of the water injection well during betting is obtained; h is_eoIs the effective thickness of the production well; c₃Is the third normalization coefficient; { Pa 3' }_0.5Is the median of the Pa 3' sequence; { Pa 3' }_0.85Is 85 percentile of the Pa 3' sequence; recommending a third normalization coefficient C₃=10, in concrete operation, C₃Other values may be used depending on the actual situation.

Preferably, in the step S12, a blocking adjustment decision factor RMF is established according to the fourth decision factor CI, the first decision factor Pa1, the second decision factor Pa2 and the third decision factor Pa3, specifically:

using equation 7, a plugging adjustment decision factor RMF is calculated:

$\mathrm{RMF}={\mathrm{CI}}^{0.8}{\mathrm{Pa}2}^{0.8}{\sqrt{\mathrm{Pa}1\mathrm{Pa}3}}^{0.6}$ (formula 7)

When the plugging decision factor RMF is applied to make a plugging decision in step S13, the RMF values are sorted in ascending order, and a water injection well or a production well with an RMF value less than the median needs to be profile-controlled or water-blocked.

Preferably, in step S14, the blockage regulating decision factor RMF is used to calculate the cumulative oil increment Q of the blockage regulating measure representing the blockage regulating measure effect_TThe method specifically comprises the following steps:

calculating the accumulated oil increment Q of the blockage regulating measures by using a formula 8_T：

$Q_T={\left(\frac{\mathrm{aW}}{1+\mathrm{bW}}\right)}^{\mathrm{\γ}}{E}_a{\mathrm{NP}}_m\frac{1}{{(1+\mathrm{RMF})}^{\mathrm{\δ}}}$ (formula 8)

In the formula 8, W is the amount of the designed plugging agent; e_aIs the area sweep coefficient; NP_mThe residual recoverable reserve is obtained; a. b, gamma and delta are calculation coefficients which can be determined according to empirical values of the plugging adjusting target block, wherein,

a. b is a plugging capability coefficient of the plugging agent, and is obtained by fitting experimental data;

gamma is a correction coefficient of the oil increasing capacity of the plugging agent and is obtained from test data of a mine field;

and delta is an RMF adjusting and blocking factor correction coefficient and is obtained from mine field test data.

In the embodiment, the plugging control decision factor RMF based on the decision factors CI, Pa1, Pa2 and Pa3 is established, so that the defect that the existing PI decision method cannot reflect reservoir heterogeneity is overcome, and the problems that the decision factor calculation is unstable and the plugging control result prediction is poor in the profile control and water plugging well selection decision of the PI decision method in a low-permeability oilfield are solved.

Example two

In order to provide a more intuitive understanding of the application effect of the low permeability reservoir profile control and water shutoff well selection decision-making method, a specific implementation manner of the invention is described by taking a profile control and well selection decision-making process of a low permeability oil field adopting the method as an example.

Table 1 shows that twelve water injection well groups in the low permeability oil field are calculated by applying the profile control, water shutoff and well selection decision method for the low permeability oil reservoir provided in the first embodiment, and the obtained results of the plugging control decision factors RMF are as follows:

TABLE 1

Well group numbering	CI	Pa1	Pa2	Pa3	RMF
						Well group 1	4.03	1.75	0.4	0.02	0.5
Well group 2	13.06	1.75	0.15	4.02	3.1
						Well group 3	6.89	0.65	0.17	1.98	1.25
Well group 4	0.36	1.08	0.19	0	0.01
						Well group 5	1.84	17.17	0.09	4.88	0.88
Well group 6	0.34	1.55	0.54	5.99	0.51
						Well group 7	13	0.77	0.44	0.02	1.18
Well group 8	2.09	9.69	0.58	3.2	3.25
						Well group 9	15.95	3.41	1.01	0.14	7.34
Well group 10	5.8	2.04	0.42	5.69	4.26
						Well group 11	1.79	0.86	0.68	2.1	1.39
Well group 12	1.64	4.72	0.54	0.01	0.38

Table 2 shows the profile control and well selection decision results determined after the plugging control decision factors RMF are arranged in ascending order:

TABLE 2

Well group numbering	RMF	Decision making conclusions
			Well group 4	0.01	Profile control well
Well group 12	0.38	Profile control well
			Well group 1	0.5	Profile control well
Well group 6	0.51	Profile control well
			Well group 5	0.88	Profile control well
Well group 7	1.18	Profile control well
			Well group 3	1.25	Untreated well
Well group 11	1.39	Untreated well
			Well group 2	3.1	Untreated well
Well group 8	3.25	Untreated well
			Well group 10	4.26	Untreated well
Well group 9	7.34	Untreated well

EXAMPLE III

In order to provide a more intuitive understanding of the application effect of the low permeability reservoir profile control and water shutoff and well selection decision-making method, a specific implementation manner of the invention is described by taking a certain low permeability oil field water shutoff and well selection decision-making process adopting the method as an example.

Table 3 shows the results of the plugging decision factor RMF obtained by calculating the fourteen oil production wells of the low permeability oil field by using the method for determining profile control, water plugging and well selection for a low permeability reservoir provided in the first embodiment (in this embodiment, Pa3 is regarded as 1 by default):

TABLE 3

Table 4 shows the decision results of the water shutoff and well selection determined after the plugging adjustment decision factors RMF are arranged in ascending order:

TABLE 4

Number of well	RMF	Decision making conclusions
			Oil recovery well 8	0.15	Water plugging well
Oil recovery well 10	0.16	Water plugging well
			Oil recovery well 4	0.27	Water plugging well
Production well 14	0.46	Water plugging well
			Production well 12	0.51	Water plugging well
Oil recovery well 3	1.71	Water plugging well
			Oil recovery well 11	1.78	Water plugging well
Production well 13	3.07	Untreated well
			Oil recovery well 1	5.58	Untreated well
Oil recovery well 5	5.83	Untreated well
			Production well 2	6.81	Untreated well
Oil recovery well 6	7.92	Untreated well
			Oil recovery well 9	10.66	Untreated well
Oil recovery well 7	32.29	Untreated well

The method has a simple structure, solves the problems of unstable calculation result and poor effect predictability when the PI decision is applied to the low-permeability oil reservoir, and realizes the scientific decision for profile control and water shutoff of the low-permeability oil reservoir.

The above-mentioned embodiments are intended to illustrate the objects, technical solutions and advantages of the present invention in further detail, and it should be understood that the above-mentioned embodiments are only exemplary embodiments of the present invention, and are not intended to limit the scope of the present invention, and any modifications, equivalent substitutions, improvements and the like made within the spirit and principle of the present invention should be included in the scope of the present invention.

Claims (7)

1. A low permeability reservoir profile control water shutoff well selection decision method is characterized by comprising the following steps:

respectively calculating a fourth decision factor CI reflecting the injectability of the plugging agent, a first decision factor Pa1 representing the intralayer heterogeneity, a second decision factor Pa2 representing the interlaminar heterogeneity and a third decision factor Pa3 representing the planar heterogeneity;

establishing a blocking regulation decision factor RMF according to the fourth decision factor CI, the first decision factor Pa1, the second decision factor Pa2 and the third decision factor Pa 3;

applying the plugging adjustment decision factor RMF to carry out plugging adjustment and well selection decisions;

calculating the accumulative oil increment Q of the blockage regulating measure for indicating the effect of the blockage regulating measure by utilizing the blockage regulating decision factor RMF_T。

2. The method according to claim 1, wherein the calculating of the fourth decision factor CI is specifically:

respectively determining the end time t of the well-storage control stage of each water injection well or oil production well in the low-permeability oil field according to the pressure test curve log-log graph_cAnd t_cCorresponding pressure change Δ p in the effective time pressure data_cEffective time-pressure data end time t_eAnd t_eCorresponding pressure change Δ p in the effective time pressure data_e、t_cTime and t_eIntermediate time t of time₁And t₁Corresponding pressure change Δ p in the effective time pressure data₁(ii) a Wherein,

the well reservoir coefficient C is calculated using the following formula:

$C=\frac{Q_{\mathrm{inj}}{t}_c}{\mathrm{\Δ}{p}_c}$

wherein Q is_injThe current daily water injection quantity of the water injection well or the current daily liquid production quantity of the oil production well;

the formation permeability k is calculated using the following formula₁、k₂；

Wherein, Δ t₁′、Δt_e′、Δp₁′、Δp_e′、Q₁、Q_eIs an intermediate parameter; for the profile control of a water injection well,

the method comprises the following steps of (1) obtaining an arithmetic average value of the viscosity of oil and water of a first-line oil production well of a water injection well after weighted calculation according to the current water content; for the water plugging of the oil production well,

the viscosity is obtained by weighting and calculating the viscosity of oil and water according to the water content; b is a volume coefficient; h is_ewIs the effective thickness; eta is the pressure conduction coefficient; k is a radical of_e2Is the current reservoir permeability; r is_eIs the feed radius; p is a radical of_tubIs the tubing pressure; c_tThe compression coefficient is the comprehensive compression coefficient of the crude oil; r is_wIs the wellbore radius;

the fourth decision factor CI is calculated using the following formula:

$\left\{\begin{array}{c}\mathrm{IC}0=\frac{1}{\sqrt{k_1{k}_2}}\\ \mathrm{CI}=C_1\frac{\mathrm{CI}0}{\frac{Q_{\mathrm{inj}}}{h_{\mathrm{ew}}}}\frac{{\stackrel{\‾}{Q}}_{\mathrm{inj}}}{{\stackrel{\‾}{h}}_{\mathrm{ew}}}\end{array}\right.$

wherein CI0 is an unnormalized fourth decision factor;

for water injection wells or oil production wells_injAn arithmetic mean of the values;h for water injection well or oil production well_ewAn arithmetic mean of the values; c₁Is the first normalization coefficient.

3. The method according to claim 1, wherein the calculating of the first decision factor Pa1 is specifically:

the first decision factor Pa1 is calculated using the following formula:

$\mathrm{Pa}1=C_2\frac{Q_w}{\mathrm{\Δ}{{\stackrel{\‾}{f}}_w}^3{h}_{\mathrm{ew}}}$

wherein, C₂Is a second normalization coefficient; for water injection wells, Q_w(ii) an accumulated water injection volume since a bet was placed for the water injection well; for oil wells, Q_wThe accumulated liquid production of the oil production well after betting for the affected water injection well; in the case of a water injection well,

the difference value of the arithmetic mean value of the current water content of the first-line oil production well and the arithmetic mean value of the corresponding water content when the effective water injection well bets is obtained; in the case of an oil-producing well,

the difference value of the current water content and the corresponding water content when the effective water injection well bets is obtained.

4. The method according to claim 1, wherein the calculating of the second decision factor Pa2 is specifically:

the second decision factor Pa2 is calculated using the following formula:

$\mathrm{Pa}2=\frac{k_{e1}}{k_{e2}}$

wherein k is_e1The permeability of the reservoir during the production of the water injection well or the oil production well.

5. The method according to claim 1, wherein the calculating a third decision factor Pa3 is specifically:

for a water plugging decision of the oil production well, determining a third decision factor Pa3= 1;

for a water injection well profile control decision, a third decision factor Pa3 is calculated using the following formula:

$\left\{\begin{array}{c}\mathrm{Pa}{3}^{\′}=\frac{Q_o}{\mathrm{\Δ}{f_w}^3{h}_{\mathrm{eo}}}\\ \mathrm{Pa}3=C_3\{1-\frac{{\left\{\mathrm{Pa}{3}^{\′}\right\}}_{0.85}-{\left\{\mathrm{Pa}{3}^{\′}\right\}}_{0.5}}{{\left\{\mathrm{Pa}{3}^{\′}\right\}}_{0.5}}\}\end{array}\right.$

wherein Pa 3' is a decision value corresponding to each production well of the first line; q_oThe accumulated oil production of each first-line oil production well after betting for the affected water injection well; Δ f_wThe difference value of the current water content of the first-line oil production well and the corresponding water content of the water injection well during betting is obtained; h is_eoIs the effective thickness of the production well; c₃Is the third normalization coefficient; { Pa 3' }_0.5Is the median of the Pa 3' sequence; { Pa 3' }_0.85Is 85 percentile of the Pa 3' sequence.

6. The method according to claim 1, wherein the blocking decision factor RMF is established based on a fourth decision factor CI, a first decision factor Pa1, a second decision factor Pa2, and a third decision factor Pa3, specifically:

calculating a blockage decision factor RMF by using the following formula:

$\mathrm{RMF}={\mathrm{CI}}^{0.8}{\mathrm{Pa}2}^{0.8}{\sqrt{\mathrm{Pa}1\mathrm{Pa}3}}^{0.6}.$

7. the method according to claim 1, wherein the accumulated oil increment Q of the blockage regulating measure is calculated by utilizing a blockage regulating decision factor RMF_TThe method specifically comprises the following steps:

the accumulated oil increment Q of the predictive plugging regulation measure is calculated by using the following formula_T：

$Q_T={\left(\frac{\mathrm{aW}}{1+\mathrm{bW}}\right)}^{\mathrm{\γ}}{E}_a{\mathrm{NP}}_m\frac{1}{{(1+\mathrm{RMF})}^{\mathrm{\δ}}}$

Wherein W is the designed plugging agent dosage; e_aIs the area sweep coefficient; NP_mThe residual recoverable reserve is obtained; a. b, gamma and delta are calculation coefficients.

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