A method for judging the rationality of reservoir development policy in the ultra-high water-cut period

Abstract

The present invention belongs to the technical field of oilfield development, and relates to a method for judging the rationality of development policies for oil reservoirs in the ultra-high water-cut period. The method comprises: selecting displacement pressure gradient field and seepage resistance field as judgment indicators; establishing a numerical simulation similarity model for unit or block oil reservoirs, and calculating displacement pressure gradient parameter field and seepage resistance parameter field; using the Tanimoto coefficient method to solve the vector similarity between the two judgment parameter fields, so as to measure the matching relationship between the development status equilibrium parameter field and the flow field equilibrium parameter field; according to the judgment results of the similarity of the two fields and the increase in the degree of recovery under different flow field adjustment schemes, a curve chart is drawn to quantitatively characterize the potential size of flow field adjustment. The method can solve the practical problem of quantitatively judging whether an ultra-high water-cut oil reservoir has the potential to implement flow field adjustment, and can effectively promote the popularization and application of ultra-high water-cut flow field adjustment technology in actual units or blocks.

Description

Technical Field

[0001] The invention belongs to the technical field of oilfield development and relates to a method for judging the rationality of an oil reservoir development policy in an ultra-high water-cut period. Background Art

[0002] The comprehensive water cut of the medium- and high-permeability reservoirs in Shengli Oilfield has reached or exceeded 90%, indicating that the overall development stage has entered the ultra-high water-cut period. There is still considerable potential for the development of remaining oil in the ultra-high water-cut period, but the water phase permeability rises sharply, the water phase seepage capacity mutates, and the water-oil ratio increases sharply, resulting in high development costs. In recent years, the ultra-high water-cut period flow field adjustment technology developed for the development of Shengli's medium- and high-permeability water-driven oil reservoirs can effectively curb high water consumption, improve water injection utilization, balance flow fields, and reduce costs. It is an important means to enhance the stable production foundation, improve development effects, and further improve water-driven recovery during the ultra-high water-cut period of the integrated oil reservoir. How to quantitatively identify whether a unit or block has the development potential for implementing flow field adjustment is of vital importance to the promotion and application of flow field adjustment technology in the ultra-high water-cut period.

[0003] Chinese invention patent CN108301813B discloses a development and adjustment method for a multi-layer sandstone reservoir with scattered sand body development, comprising: step 1, conducting detailed reservoir geological research and geological modeling; step 2, establishing a numerical model; step 3, using numerical models and combining reservoir engineering methods to conduct residual oil distribution research; step 4, conducting a feasibility study on multiple rounds of stratum rotation; step 5, evaluating stratum rotation resources; step 6, designing multiple rounds of stratum rotation plans; step 7, conducting indicator prediction and economic evaluation, and implementing the plan.

[0004] Chinese invention patent CN104794361B discloses a comprehensive evaluation method for water-flooding reservoir development effect, including the following steps: A. Determine and classify the set of factors affecting the water-flooding development effect; B. Determine the evaluation comment set; C. Use the entropy weight method to obtain the objective weight, use the hierarchical analysis method to obtain the subjective weight, and use the dynamic assignment method to determine the final weight of each factor; D. Perform a first-level fuzzy evaluation on the water-flooding development effect; E. Use multiple fuzzy synthesis operators to correct the evaluation results; F. Iterate the above calculation process to achieve a multi-level fuzzy comprehensive evaluation of the water-flooding reservoir development effect.

[0005] Chinese invention patent CN105626055B discloses a method for evaluating the quality of reserves in an extremely high water-cut period oil reservoir. The method comprises: step 1, conducting a detailed geological feature study; step 2, evaluating the reservoir development status, including classifying the sand bodies and calculating the reserves; step 3, analyzing the reserves production status; and step 4, evaluating the quality of reserves production.

[0006] However, there is currently no solution to the problem of how to quantitatively identify whether a unit or block has the development potential for implementing flow field adjustment. Summary of the invention

[0007] The main purpose of the present invention is to provide a method for judging the rationality of the development policy of an oil reservoir in a very high water cut period. The method of the present invention solves the problem of unclear development policy for flow field adjustment of an oil reservoir in a very high water cut period.

[0008] To achieve the above object, the present invention adopts the following technical solutions:

[0009] The present invention provides a method for judging the rationality of an oil reservoir development policy in an ultra-high water cut period, comprising the following steps:

[0010] For the reservoirs in the extra-high water-cut period, a numerical simulation similarity model of unit or block reservoirs is established. From the perspectives of development status and flow field equilibrium, displacement pressure gradient field and seepage resistance field are selected as indicators for judging the rationality of flow field adjustment development policy.

[0011] By setting different injection-production condition schemes, simulating the same recovery degree, respectively simulating the prediction of the effect of improving oil recovery by carrying out streamline adjustment under different injection-production condition schemes, and calculating the development status equilibrium identification index when implementing streamline adjustment under different injection-production condition schemes, that is, the reservoir displacement pressure gradient parameter field;

[0012] Calculate the flow field equilibrium identification index when implementing streamline adjustment under different injection and production conditions, i.e., the reservoir seepage resistance parameter field;

[0013] The Tanimoto coefficient method is used to solve the vector similarity between the displacement pressure gradient parameter field and the seepage resistance parameter field, so as to measure the matching relationship between the development status equilibrium parameter field and the flow field equilibrium parameter field.

[0014] According to the identification results of the similarity between the two fields and the increase in recovery rate under different flow field adjustment schemes, a curve chart of the similarity between the two fields and the increase in recovery rate is drawn, so as to quantitatively identify the flow field adjustment potential of the reservoir.

[0015] Furthermore, the ultra-high water-cut oil reservoir refers to a unit or block in which the injection-production well pattern remains unchanged for a long time, and the injection-production flow lines are fixed for a long time, resulting in unbalanced displacement.

[0016] Furthermore, the unit or block reservoir numerical simulation similarity model refers to a similar reservoir numerical simulation model established based on the similarity criterion, which reflects the average permeability, average effective thickness, average original oil saturation, oil-water phase density and viscosity, relative permeability curve, production rate, well network form and other characteristics of the unit or block.

[0017] Furthermore, the different injection and production condition schemes refer to setting up relevant working systems of different daily liquid production of oil wells and daily water injection volumes of water wells in similar models, implementing flow field adjustment when simulating the same recovery degree, and predicting the recovery degree improvement index 10 years after the flow field adjustment.

[0018] Furthermore, the calculation method of the reservoir displacement pressure gradient parameter field includes:

[0019] The pressure gradient in the i direction can be derived from Darcy's formula:

[0020]

[0021] Similarly, the pressure gradients in the j and k directions are obtained:

[0022]

[0023] Then the displacement pressure gradient of any grid is:

[0024]

[0025] in:

[0026] Q i , Q j , Q k are the oil phase seepage velocities in directions i, j, and k, respectively;

[0027] TRAN i , TRAN j , TRAN k are the conductivity in directions i, j and k respectively;

[0028] Mobility is the mobility coefficient, and its calculation formula is:

[0029]

[0030] are the displacement pressure gradients in directions i, j, and k, respectively;

[0031] is the displacement pressure gradient after superposition of any grid i, j, and k directions.

[0032] Furthermore, the above static parameter field TRAN i , TRAN j , TRAN k , dynamic parameter field Q i , Q j , Q k It is obtained from the simulation results of reservoir numerical simulation software Eclipse or Petrel-RE, where the dynamic parameter field data is defined and output in RPTRST, Q i, Q j , Q k Output through keyword FLORES, Mobility according to formula 1, output through keywords KRO, VOIL, BO respectively, static field data TRAN i , TRAN j , TRAN k In the RPTGRID keyword, by defining TRAN i , TRAN j , TRAN k Output.

[0033] Furthermore, the calculation model of reservoir seepage resistance parameter field is:

[0034]

[0035] in:

[0036] R is the seepage resistance;

[0037] K o , K w are the effective permeabilities of oil and water phase, respectively;

[0038] μ o , μ w are the viscosities of the oil and water phases, respectively.

[0039] Furthermore, the Tanimoto coefficient method is used to solve the calculation formula of the vector similarity between the displacement pressure gradient parameter field and the seepage resistance parameter field:

[0040]

[0041] Range: [0,1];

[0042] Among them, the displacement pressure gradient parameter field and the seepage resistance parameter field are 1 when they completely overlap, and 0 when there is no overlapping term. The closer to 1, the more similar they are.

[0043] Furthermore, according to the curve chart, it can be divided into two types of areas: two-field basic matching area and non-matching area. In the two-field basic matching area, it indicates that the flow field adjustment potential is large, and it is reasonable to implement the flow field adjustment development policy; otherwise, it indicates that the flow field adjustment potential is small, and it is unreasonable to implement the flow field adjustment development policy;

[0044] Furthermore, when the similarity between the two fields is less than 0.6, it is a basic matching area; when the similarity between the two fields is greater than 0.6, it is a non-matching area.

[0045] Furthermore, in the curve chart, the X-axis is the similarity between two flow field adjustment schemes under different injection-production conditions, and the Y-axis is the improvement in the production degree of the flow field adjustment scheme under the injection-production conditions.

[0046] Compared with the prior art, the present invention has the following beneficial effects:

[0047] The method of the present invention solves the practical problem of quantitatively identifying whether an oil reservoir in the ultra-high water-cut period has the potential for implementing flow field adjustment, and can effectively promote the popularization and application of flow field adjustment technology in the ultra-high water-cut period in actual units or blocks. BRIEF DESCRIPTION OF THE DRAWINGS

[0048] The accompanying drawings in the specification, which constitute a part of the present invention, are used to provide a further understanding of the present invention. The exemplary embodiments of the present invention and their descriptions are used to explain the present invention and do not constitute improper limitations on the present invention.

[0049] Figure 1 This is a flow chart of a method for determining the rationality of an oil reservoir development policy in an ultra-high water-cut period according to a specific embodiment of the present invention;

[0050] Figure 2 It is a schematic diagram of a similar model well pattern for flow field simulation according to a specific embodiment of the present invention;

[0051] Figure 3 It is a displacement pressure gradient parameter field diagram for implementing the variable flow line adjustment time according to a specific embodiment of the present invention;

[0052] Figure 4 It is a seepage resistance parameter field diagram when implementing the variable streamline adjustment described in a specific embodiment of the present invention;

[0053] Figure 5 It is a curve chart of the matching degree between the flow field adjustment displacement pressure gradient field and the seepage resistance field according to a specific embodiment of the present invention. DETAILED DESCRIPTION

[0054] It should be noted that the following detailed descriptions are exemplary and are intended to provide further explanation of the present invention. Unless otherwise specified, all technical and scientific terms used herein have the same meanings as those commonly understood by those skilled in the art to which the present invention belongs.

[0055] It should be noted that the terms used herein are only for describing specific embodiments and are not intended to limit exemplary embodiments according to the present invention. As used herein, unless the context clearly indicates otherwise, the singular form is also intended to include the plural form. In addition, it should be understood that when the terms "comprising" and / or "including" are used in this specification, it indicates the presence of features, steps, operations and / or combinations thereof.

[0056] In order to enable those skilled in the art to more clearly understand the technical solution of the present invention, the technical solution of the present invention will be described in detail below in conjunction with specific embodiments.

[0057] The extremely high water-cut reservoir described in the following embodiments refers to a unit or block in which the injection-production well pattern remains unchanged for a long time, and the injection-production flow line is fixed for a long time, resulting in unbalanced displacement.

[0058] Example 1 A method for judging the rationality of the development policy of an extremely high water-cut oil reservoir

[0059] like Figure 1 As shown, the method for judging the rationality of the development policy of the ultra-high water-cut reservoir comprises the following steps:

[0060] Step 1. For the ultra-high water-cut reservoirs, based on the similarity criterion, a numerical simulation model of similar reservoirs is established to reflect the average permeability, average effective thickness, average original oil saturation, oil-water phase density and viscosity, relative permeability curve, production rate, well network form and other characteristics of the unit or block; considering the development status and flow field balance, the displacement pressure gradient field and seepage resistance field are selected as indicators for judging the rationality of the flow field adjustment development policy.

[0061] Step 2. By setting different injection-production condition schemes, simulating to the same recovery degree, respectively simulating the prediction of the effect of improving oil recovery by carrying out streamline adjustment under different injection-production condition schemes, and calculating the development status equilibrium identification index when implementing streamline adjustment under different injection-production condition schemes, that is, the reservoir displacement pressure gradient parameter field;

[0062] The different injection and production condition schemes refer to setting up relevant working systems with different daily liquid production of oil wells and daily water injection volumes of water wells in similar models, implementing flow field adjustment when simulating the same recovery degree, and predicting the recovery degree improvement index 10 years after the flow field adjustment.

[0063] The calculation method of reservoir displacement pressure gradient parameter field includes:

[0064] The pressure gradient in the i direction can be derived from Darcy's formula:

[0065]

[0066] Similarly, the pressure gradients in the j and k directions are obtained:

[0067]

[0068] Then the displacement pressure gradient of any grid is:

[0069]

[0070] in:

[0071] Q i , Q j , Q k are the oil phase seepage velocities in directions i, j, and k, respectively;

[0072] TRAN i , TRAN j , TRAN k are the conductivity in directions i, j and k respectively;

[0073] Mobility is the mobility coefficient, and its calculation formula is:

[0074]

[0075] are the displacement pressure gradients in directions i, j, and k, respectively;

[0076] is the displacement pressure gradient after superposition of any grid i, j, and k directions.

[0077] Furthermore, the above static parameter field TRAN i , TRAN j , TRAN k , dynamic parameter field Q i , Q j , Q k It is obtained from the simulation results of reservoir numerical simulation software Eclipse or Petrel-RE, where the dynamic parameter field data is defined and output in RPTRST, Q i , Q j , Q k Output through keyword FLORES, Mobility according to formula 1, output through keywords KRO, VOIL, BO respectively, static field data TRAN i , TRAN j , TRAN k In the RPTGRID keyword, by defining TRAN i , TRAN j , TRAN k Output.

[0078] Step 3. Calculate the flow field equilibrium identification index at the time of streamline adjustment for different injection and production condition schemes, i.e., the reservoir seepage resistance parameter field;

[0079] The calculation model of reservoir seepage resistance parameter field is:

[0080]

[0081] in:

[0082] R is the seepage resistance;

[0083] K o , K w are the effective permeabilities of oil and water phase, respectively;

[0084] μ o , μ w are the viscosities of the oil and water phases, respectively.

[0085] Step 4. Use the Tanimoto coefficient method to solve the vector similarity between the displacement pressure gradient parameter field and the seepage resistance parameter field, so as to measure the matching relationship between the development status equilibrium parameter field and the flow field equilibrium parameter field;

[0086] The calculation formula for solving the vector similarity between the displacement pressure gradient parameter field and the seepage resistance parameter field using the Tanimoto coefficient method is:

[0087]

[0088] Range: [0,1];

[0089] Among them, the displacement pressure gradient parameter field and the seepage resistance parameter field are 1 when they completely overlap, and 0 when there is no overlapping term. The closer to 1, the more similar they are.

[0090] Step 5. Based on the identification results of the similarity between the two fields and the increase in the degree of recovery under different flow field adjustment schemes, a curve chart of the similarity between the two fields and the increase in the degree of recovery is drawn to quantitatively identify the potential for reservoir flow field adjustment.

[0091] In the curve chart, the X-axis is the similarity between the two flow field adjustment schemes under different injection-production conditions, and the Y-axis is the improvement in the production degree of the flow field adjustment scheme under the injection-production conditions.

[0092] According to the curve chart, it can be divided into two types of areas: two-field basic matching area and non-matching area. In the two-field basic matching area, it indicates that the flow field adjustment potential is large, and it is reasonable to implement the flow field adjustment development policy; on the contrary, it indicates that the flow field adjustment potential is small, and it is unreasonable to implement the flow field adjustment development policy.

[0093] When the similarity between the two fields is less than 0.6, it is a basic matching area; when the similarity between the two fields is greater than 0.6, it is a mismatching area.

[0094] Example 2

[0095] Taking the establishment of a similar model for water flooding development of an oil reservoir in an extremely high water cut period as an example, the implementation process and effects of the present invention are specifically described.

[0096] 1. Select indicators to judge the rationality of flow field adjustment development policy

[0097] According to the similarity criterion, referring to the characteristics of the average permeability and average effective thickness of typical units in the high water cut period of the Shengli Oilfield, a streamline simulation similarity model was established. The plane grid number is 63×63, the grid step size is 10m×10m, and it is divided into 2 layers vertically. The total number of model grids is 7938, and the specific parameters of the layers are shown in Table 1. There are two simulated small layers in the vertical direction, and 6 injection and 3 production and 6 injection and 6 production well patterns are set respectively (see Table 1). Figure 2 ), liquid collection speed 10%.

[0098] Table 1 Parameters of similar model for flow field simulation

[0099]

[0100] Through the Eclipse streamline simulator, 6 different injection and production condition schemes were set (see Table 2), and the same recovery degree condition (40%) was simulated to simulate the effect of improving the recovery rate by implementing the variable streamline adjustment in different injection and production schemes. Considering the development status and flow field equilibrium, the displacement pressure gradient field and seepage resistance field at the time of implementing the variable streamline adjustment were selected as the rationality identification indicators of the flow field adjustment development policy.

[0101] Table 2 Injection and production volume parameter settings for six different injection and production schemes (unit: m 3 / d)

[0102] Solution No. Solution 1 Solution 2 Solution 3 Solution 4 Solution 5 Solution 6 Oil Well Liquid output 1 Liquid output 2 Liquid output 3 Liquid output 4 Liquid output 5 Liquid output 6 1-2 90 80 50 66 40 25 1-5 20 40 100 67 120 150 1-8 90 80 50 67 40 25 2-2 45 40 25 33 20 15 2-4 10 20 50 33 60 70 2-6 10 20 50 33 60 70 2-8 45 40 25 33 20 15 2-10 45 40 25 34 20 15 2-12 45 40 25 34 20 15 well Water injection volume 1 Water injection 2 Water injection volume 3 Water injection volume 4 Water injection volume 5 Water injection volume 6 1-1 45 40 25 33 20 15 1-3 45 40 25 33 20 15 1-4 10 20 50 33 60 70 1-6 10 20 50 33 60 70 1-7 45 40 25 34 20 15 1-9 45 40 25 34 20 15 2-1 45 40 25 33 20 15 2-3 45 40 25 33 20 15 2-5 45 40 25 33 20 15 2-7 10 20 50 33 60 70 2-9 10 20 50 34 60 70

[0103] 2. Calculate the displacement pressure gradient parameter field at the flow field adjustment time

[0104] (1) The Floviz module of Eclipse reservoir numerical simulation software is used to output the dynamic parameter fields FLOIOLI+, FLOOILJ+, and FLOOILK+ that characterize the flow in the directions of any grid i, j, and k through the keyword FLORES.

[0105] (2) The static parameter field representing the flow coefficient Mobiliyt is output through the keywords KRO, VOIL, and BO respectively.

[0106] (3) By defining TRAN in the keyword RPTGRID i , TRAN j , TRAN k Output conductivity static parameter field TRAN i , TRAN j , TRAN k .

[0107] (4) In the Floviz module, define the pressure gradient parameters in the i, j, and k directions according to the displacement pressure gradient calculation formula And the displacement pressure gradient after superposition of i, j, and k directions Finally, the displacement pressure gradient parameter fields of the two simulation layers are output respectively (see Figure 3 ).

[0108] 3. Calculate the seepage resistance parameter field at the time of streamline development adjustment

[0109] (1) Using the Floviz module of Eclipse reservoir numerical simulation software, the static parameter fields representing the viscosity of oil and water are output through the keywords VOIL and BO respectively;

[0110] (2) The dynamic parameter field representing water saturation is output through the keyword SWAT, and the relationship between oil and water relative permeability and water saturation is calculated based on the oil-water relative permeability curve;

[0111] (3) In the Floviz module, the seepage resistance parameter R of any grid is defined according to the seepage resistance calculation formula, and the seepage resistance parameter field is finally output (see Figure 4 ).

[0112] 4. Solve the vector similarity of two identification parameter fields

[0113] (1) The displacement pressure gradient parameter field and seepage resistance parameter field of the two simulation layers are converted into n-dimensional vectors respectively;

[0114] (2) The Tanimoto coefficient method is used to solve the similarity between the displacement pressure gradient parameter field vector and the seepage resistance parameter field vector (see Table 3).

[0115] Table 3 Calculation results of similarity between displacement pressure gradient field and seepage resistance field

[0116]

[0117]

[0118] 5. Draw a chart to judge the rationality of flow field adjustment and development policy

[0119] (1) According to the numerical simulation results of implementing variable flow line adjustment under different injection and production conditions, the effect of implementing variable flow line adjustment to improve the recovery degree is statistically analyzed starting from the time when the recovery degree reaches 40% (see Table 4);

[0120] (2) Draw the relationship curve between the similarity of displacement pressure gradient field and seepage resistance field and the increase in recovery degree, and establish a matching curve chart between the two fields (see Figure 5 ).

[0121] Table 4 Results of identification of matching between two fields under different injection and production conditions

[0122]

[0123] Depend on Figure 5 It can be seen that the displacement pressure gradient field and the seepage resistance field show an obvious "negative" matching relationship. When the similarity of the two fields is <0.6, it is a basic matching area, indicating that the reservoir has a large potential for flow field adjustment at this time, and it is reasonable to implement a flow field adjustment development policy; when the similarity of the two fields is >0.6, it is a mismatching area, indicating that the flow field adjustment potential is small, and it is unreasonable to implement a flow field adjustment development policy.

[0124] The present invention will make the water flooding development adjustment technology in the ultra-high water cut period more perfect, especially provide strong technical support and guarantee for the flow field adjustment in the ultra-high water cut period of the monolithic medium and high permeability sandstone reservoir.

[0125] The embodiments of the present invention are described above in conjunction with the accompanying drawings, but the present invention is not limited to the above-mentioned specific implementation methods, which are merely illustrative and not restrictive. The above description does not impose any formal limitation on the present invention. Although the present invention is disclosed through the above-mentioned embodiments, it is not used to limit the present invention. Any technician familiar with the profession can make some changes or modifications to equivalent embodiments of equivalent changes using the technical contents disclosed above without departing from the scope of the technical solution of the present invention. However, any simple modification, equivalent changes and modifications made to the above embodiments based on the technical essence of the present invention without departing from the content of the technical solution of the present invention still belong to the scope of the technical solution of the present invention.

Claims

1. A method for judging the rationality of reservoir development policy in the ultra-high water-cut period. It is characterized in that The following steps are involved: For the reservoirs in the extra-high water-cut period, a numerical simulation similarity model of unit or block reservoirs is established. From the perspectives of development status and flow field equilibrium, displacement pressure gradient field and seepage resistance field are selected as indicators for judging the rationality of flow field adjustment development policy. By setting different injection-production condition schemes, simulating the same recovery degree, respectively simulating the prediction of the effect of improving oil recovery by carrying out streamline adjustment under different injection-production condition schemes, and calculating the development status equilibrium identification index when implementing streamline adjustment under different injection-production condition schemes, that is, the reservoir displacement pressure gradient parameter field; Calculate the flow field equilibrium identification index when implementing streamline adjustment under different injection and production conditions, i.e., the reservoir seepage resistance parameter field; The Tanimoto coefficient method is used to solve the vector similarity between the displacement pressure gradient parameter field and the seepage resistance parameter field, so as to measure the matching relationship between the development status equilibrium parameter field and the flow field equilibrium parameter field. According to the identification results of the similarity between the two fields and the increase in recovery rate under different flow field adjustment schemes, a curve chart of the similarity between the two fields and the increase in recovery rate is drawn to quantitatively identify the potential of reservoir flow field adjustment; The calculation method of reservoir displacement pressure gradient parameter field includes: The pressure gradient in the i direction can be derived from Darcy's formula: Similarly, the pressure gradients in the j and k directions are obtained: Then the displacement pressure gradient of any grid is: in: Q i , Q j , Q k are the oil phase seepage velocities in directions i, j, and k, respectively; TRAN i , TRAN j , TRAN k are the conductivity in directions i, j and k respectively; Mobility is the mobility coefficient, and its calculation formula is: They are the displacement pressure gradients in the i, j, and k directions respectively; is the displacement pressure gradient after superposition of directions of any grid i, j, and k; The calculation model of reservoir seepage resistance parameter field is: in: R is the seepage resistance; K o , K w are the effective permeabilities of oil and water phase, respectively; μ o , μ w are the viscosities of the oil and water phases, respectively.

2. The method according to claim 1, It is characterized in that The so-called ultra-high water-cut oil reservoir refers to a unit or block in which the injection-production well pattern remains unchanged for a long time, and the injection-production flow line is fixed for a long time, resulting in unbalanced displacement.

3. The method according to claim 1, It is characterized in that The unit or block reservoir numerical simulation similarity model refers to a reservoir numerical simulation model that is established based on the similarity criterion to reflect the average permeability, average effective thickness, average original oil saturation, oil-water phase density and viscosity, relative permeability curve, liquid production rate and well network form of the unit or block.

4. The method according to claim 1, It is characterized in that The different injection and production condition schemes refer to setting up relevant working systems of different daily liquid production of oil wells and daily water injection volumes of water wells in similar models, implementing flow field adjustment when simulating the same recovery degree, and predicting the recovery degree improvement index 10 years after the flow field adjustment.

5. The method according to claim 4, It is characterized in that Static parameter field TRAN i , TRAN j , TRAN k , dynamic parameter field Q i , Q j , Q k It is obtained from the simulation results of reservoir numerical simulation software Eclipse or Petrel-RE, where the dynamic parameter field data is defined and output in RPTRST, Q i , Q j , Q k The output is through the keyword FLORES. Mobility is output through the keywords KRO, VOIL, and BO according to formula (1). The static field data TRAN i , TRAN j , TRAN k In the RPTGRID keyword, by defining TRAN i , TRAN j , TRAN k Output.

6. The method according to claim 1, It is characterized in that The calculation formula for solving the vector similarity between the displacement pressure gradient parameter field and the seepage resistance parameter field using the Tanimoto coefficient method is: Range: [0,1]; Among them, the displacement pressure gradient parameter field and the seepage resistance parameter field are 1 when they completely overlap, and 0 when there is no overlapping term. The closer to 1, the more similar they are.

7. The method according to claim 1, It is characterized in that According to the curve chart, it can be divided into two types of areas: two-field basic matching area and non-matching area. In the two-field basic matching area, it indicates that the flow field adjustment potential is large, and it is reasonable to implement the flow field adjustment development policy; on the contrary, it indicates that the flow field adjustment potential is small, and it is unreasonable to implement the flow field adjustment development policy; When the similarity between the two fields is less than 0.6, it is a basic matching area; when the similarity between the two fields is greater than 0.6, it is a mismatching area.

8. The method according to claim 1 or 7, It is characterized in that In the curve chart, the X-axis is the similarity between the two flow field adjustment schemes under different injection-production conditions, and the Y-axis is the degree of improvement in the production degree of the flow field adjustment scheme under the injection-production conditions.

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