Water control method and device for water-flooding development of heterogeneous reservoir

Abstract

The invention discloses a water control method and device for water-flooding development of a heterogeneous oil reservoir. The method comprises the steps that according to the position relation between a well track and a high-permeability layer, the water content and the recovery degree, water control objects are screened out from a horizontal oil well of an oil reservoir and classified and sorted; based on comparison with the resistivity curve of the passing well, preliminarily identifying the trend of a water flow channel and the remaining oil enrichment part, and determining the flooding degree of each water control object and the water saturation before water injection; on the basis of the preliminary recognition result and monthly data of the oil-water well, remaining oil enrichment part recognition is updated through dynamic fitting, and classification and sorting are adjusted in combination with the flooding degree; based on the water saturation and injection and extraction data of the water control object before water injection, the current liquid accumulation amount is determined; and formulating a water control measure implementation sequence, adjusting the working system of the water control object, and determining the ratio of the liquid accumulation amount to the water yield as the predicted liquid drainage time for the adjusted water control object. According to the method, zero-cost quality and efficiency improvement of the heterogeneous oil reservoir is realized by utilizing a difference adjustment working system.

Description

Technical Field

[0001] The invention relates to the technical field of water control for high water-content horizontal wells in heterogeneous oil reservoirs, and in particular to a water control method and device for water injection development in heterogeneous oil reservoirs. Background Art

[0002] The oil-bearing reservoirs in the Middle East are mostly highly heterogeneous layered limestone reservoirs, with high-permeability thieves generally developed at the top, causing the water injected from the lower part of the reservoir (vertical well or horizontal well) to quickly penetrate into the upper reservoir and advance to the top of the reservoir along the high-permeability strip. The water is mainly maintained in the upper high-permeability layer, and is generally "lifted" or "inverted water cone" by the injected water. The sweep efficiency of the lower reservoir is very low, and the potential for residual oil development is large. Most heterogeneous reservoirs adopt the development mode of top production and bottom injection of horizontal wells as a whole. Due to the thin high-permeability layer developed at the top, the water-free oil production period of horizontal production wells after water injection development is short and the water content rises quickly after water appears. It is difficult to stabilize oil and control water in the middle and late development, and effective water control measures are urgently needed to achieve stable production and increase production. Summary of the invention

[0003] In order to at least partially solve the technical problems existing in the prior art, the inventors have made the present invention, and through a specific implementation method, provide a water control method and device for water injection development in a heterogeneous oil reservoir, which can achieve "zero cost" quality improvement and efficiency enhancement of the heterogeneous oil reservoir by adjusting the differential working system.

[0004] In a first aspect, an embodiment of the present invention provides a water control method for water injection development in a heterogeneous oil reservoir, comprising:

[0005] Step S11, according to the positional relationship between the well trajectory and the high permeability layer and the water content and recovery degree included in the single well dynamic development data, water control objects are selected from the horizontal oil wells in the oil reservoir, and classified and sorted;

[0006] Step S12, based on the comparison with the resistivity curve of the passing well, the preliminary identification results of the water flow channel direction and the remaining oil enrichment position are obtained, and the flooding degree of each water control object and the water saturation before water injection are clarified;

[0007] Step S13, based on the preliminary identification results and the monthly data of oil and water wells, the knowledge of the remaining oil-rich parts is updated through the fitting of the dynamic numerical model, and the classification and ranking of the water control objects are adjusted in combination with the degree of flooding;

[0008] Step S14, determining the current amount of liquid accumulation of the water control object based on the water saturation before water injection and the injection and production data;

[0009] Step S15, based on the adjusted classification and ranking of water control objects, formulate the implementation order of water control measures and water control measures for each water control object, determine the water production of the water control object after the implementation of the water control measures, and determine the ratio of the accumulated liquid volume to the water production volume as the predicted drainage time. The water control measure is to adjust the work system.

[0010] In a second aspect, an embodiment of the present invention provides a method for water injection development in a heterogeneous reservoir, including controlling water during the water injection development in a heterogeneous reservoir by using any of the above-mentioned water control methods for water injection development in a heterogeneous reservoir.

[0011] In a third aspect, an embodiment of the present invention provides a water control device for water injection development of a heterogeneous oil reservoir, comprising:

[0012] The module for preliminary screening and classification of water control objects is used to screen out water control objects from horizontal oil wells in the reservoir, classify and sort them according to the positional relationship between the well trajectory and the high permeability layer and the water content and recovery degree included in the dynamic development data of a single well;

[0013] The water flooding feature analysis module is used to obtain preliminary identification results of the direction of the water flow channel and the remaining oil enrichment site based on the comparison with the resistivity curve of the passing well, and to clarify the degree of water flooding of each water control object and the water saturation before water injection;

[0014] A water control object classification and ranking optimization module is used to update the knowledge of the remaining oil-enriched parts based on the preliminary identification results and the monthly data of oil and water wells through the fitting of dynamic numerical models, and adjust the classification and ranking of water control objects in combination with the degree of flooding;

[0015] The liquid accumulation calculation module is used to determine the current liquid accumulation of the water control object based on its water saturation before water injection and injection and production data;

[0016] The water control measures formulation module is used to formulate the order of implementation of water control measures and water control measures for each water control object based on the adjusted classification and ranking of water control objects, determine the water production of the water control object after the implementation of the water control measures, and determine the ratio of the accumulated liquid volume to the water production volume as the predicted drainage time. The water control measures are to adjust the work system.

[0017] In a fourth aspect, an embodiment of the present invention provides a computer storage medium, wherein the computer storage medium stores computer executable instructions, and when the computer executable instructions are executed by a processor, the above-mentioned water control method for water injection development in a heterogeneous oil reservoir is implemented.

[0018] In a fifth aspect, an embodiment of the present disclosure provides a server, comprising: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor implements the above-mentioned water control method for water injection development in heterogeneous oil reservoirs when executing the program.

[0019] The beneficial effects of the above technical solution provided by the embodiment of the present invention include at least:

[0020] (1) The water control method for water injection development of heterogeneous oil reservoirs provided in the embodiment of the present invention, through the implementation of steps S11 to S15, analyzes the development law and dynamic characteristics of high water-cut horizontal oil wells, diagnoses water flooding and identifies water flow channels, characterizes the distribution of residual oil, calculates wellbore liquid accumulation and drainage time, and designs and implements water control measures. The method provides a new water control method and process for high water-cut horizontal wells in heterogeneous oil reservoirs, thereby continuously controlling the water content of the oil wells and increasing the oil production of a single well.

[0021] (2) Since most horizontal wells are completed in open holes and the wellbore integrity is insufficient, the implementation cost of water plugging and profile control technology is high, the process is difficult, and the effective period of oil production is short. The water control method for water injection development of heterogeneous oil reservoirs provided in the embodiment of the present invention does not require any measures or construction, and does not increase additional operating costs. After diagnosing the residual oil-rich layer, the high-permeability layer liquid is removed and the low-permeability layer is used to improve the utilization of the low-permeability layer through reasonable adjustment of the oil and water well working system. Different adjustment strategies are used to fully tap the residual oil potential of high-water-content oil wells and improve the reservoir development effect. It is a new type of high-water-content horizontal well management method that can achieve "zero cost" quality improvement and efficiency enhancement of heterogeneous oil reservoirs.

[0022] Other features and advantages of the present invention will be described in the following description, and partly become apparent from the description, or understood by practicing the present invention. The purpose and other advantages of the present invention can be realized and obtained by the structures particularly pointed out in the written description, claims, and drawings.

[0023] The technical solution of the present invention is further described in detail below through the accompanying drawings and embodiments. BRIEF DESCRIPTION OF THE DRAWINGS

[0024] The accompanying drawings are used to provide a further understanding of the present invention and constitute a part of the specification. Together with the embodiments of the present invention, they are used to explain the present invention and do not constitute a limitation of the present invention. In the accompanying drawings:

[0025] Figure 1 This is a flow chart of a water control method for water injection development in a heterogeneous oil reservoir in Example 1 of the present invention;

[0026] Figure 2 This is a top production and bottom injection mode diagram of a horizontal well pattern in a row of wells in the second embodiment of the present invention;

[0027] Figure 3 The water distribution map of Kh2 reservoir in the second embodiment of the present invention;

[0028] Figure 4The saturation change monitoring of a typical horizontal injection-production well group after two and four years of water injection in Example 2 of the present invention (vertical well);

[0029] Figure 5 This is a statistical diagram of the relationship between the number of high water-cut days and the well trajectory of the high water-cut well in the second embodiment of the present invention;

[0030] Figure 6 This is an analysis chart of factors affecting the number of days high water content is maintained in a high water content well during re-production in Example 2 of the present invention;

[0031] Figure 7 This is a water content curve diagram of the AD1-11 row of production wells during the five-point method alternation period in Example 2 of the present invention;

[0032] Figure 8 It is a graph showing the moisture content variation curve (actual measurement and numerical simulation prediction trend) of AD1-13-4H in Example 2 of the present invention;

[0033] Fig. 9 This is a flow line comparison diagram of the AD1-11-3H liquid extraction and injection in Example 2 of the present invention and the basic scheme;

[0034] Fig.10 It is a schematic diagram of the structure of a water control device for water injection development of a heterogeneous oil reservoir in an embodiment of the present invention. DETAILED DESCRIPTION

[0035] The exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. Although the exemplary embodiments of the present disclosure are shown in the accompanying drawings, it should be understood that the present disclosure can be implemented in various forms and should not be limited by the embodiments set forth herein. On the contrary, these embodiments are provided to enable a more thorough understanding of the present disclosure and to fully convey the scope of the present disclosure to those skilled in the art.

[0036] It should be understood that the terms described in the present invention are only for describing special embodiments and are not intended to limit the present invention. In addition, for the numerical range in the present invention, it should be understood that each intermediate value between the upper and lower limits of the scope is also specifically disclosed. Each smaller range between the intermediate value in any stated value or stated range and any other stated value or intermediate value in the described range is also included in the present invention. The upper and lower limits of these smaller ranges can be independently included or excluded in the scope.

[0037] Unless otherwise indicated, all technical and scientific terms used herein have the same meanings as commonly understood by those skilled in the art to which the invention belongs. Although the present invention describes only preferred methods and materials, any methods and materials similar or equivalent to those described herein may also be used in the implementation or testing of the present invention. All documents mentioned in this specification are incorporated by reference to disclose and describe the methods and / or materials related to the documents. In the event of a conflict with any incorporated document, the content of this specification shall prevail.

[0038] The inventors have discovered that horizontal well trajectories commonly penetrate layers in thin-layer heterogeneous oil reservoirs. By studying the production dynamic characteristics of different types of wells that penetrate layers, the inventors analyzed the horizontal and vertical flooding characteristics with the help of logging interpretation data of water-flooded layers in passing wells, clarified the flooding rules affected by high-permeability thieves, clarified the utilization conditions of different small layers and the distribution characteristics of residual oil, and targeted the influence of the matching relationship of horizontal well trajectories on the rapid increase of water cut and screened out well groups or single wells suitable for adjustment. By applying the theoretical calculation formula for horizontal wellbore liquid accumulation and the prediction formula for drainage time, the inventors calculated the time for draining accumulated liquid in the wellbore trajectory of the high-permeability zone for different well groups or single wells. By adjusting the amount of liquid injection in the oil and water wells, the utilization of the horizontal well section in the non-high-permeability layer was expanded, thereby achieving the purpose of reducing the water cut and increasing production of high-water-cut oil wells.

[0039] Embodiment 1

[0040] Embodiment 1 of the present invention provides a method for controlling water in water injection development of a heterogeneous oil reservoir, and the process thereof is as follows Figure 1 As shown, the following steps are included:

[0041] Step S11: According to the positional relationship between the well trajectory and the high permeability layer and the water content and recovery degree included in the single well dynamic development data, water control objects are selected from the horizontal oil wells in the oil reservoir, and classified and sorted.

[0042] First, based on the dynamic development data of single wells, we start with the analysis of the development effect of production wells and the law of water content changes, clarify the differences in the effects of single wells, and count the development indicators such as water cut, cumulative oil production, and recovery degree. According to the water cut and recovery degree included in the dynamic development data of single wells, we draw the curve of water cut and recovery degree of single wells, and conduct classification analysis. According to the characteristics of the curve, the water cut rise type of horizontal oil wells in the reservoir is classified into slow water cut rise type (type 1), fast water flooding and high water cut slow rise type (type 2), fast water flooding and fast water cut rise type (type 3), sudden water flooding and high water cut slow rise type (type 4) and violent water flooding and high water cut fast rise type (type 5). It can also be further subdivided on the basis of these types.

[0043] Clarify the correspondence between water-cut rise types and influencing factors, including high-permeability layers, fractures and cracks, high-viscosity oil, bottom water and horizontal well trajectories.

[0044] According to the positional relationship between the well trajectory and the high permeability layer and the water content, on the basis of the classification results of water-cut rise types and the correspondence between water-cut rise types and influencing factors, water control objects are screened out from the horizontal oil wells in the reservoir, classified and ranked in terms of difficulty of control.

[0045] Type 1: Slow rise of water content is closely related to the horizontal well trajectory avoiding the high permeability layer, Type 2: Rapid water flooding + high water content slow rise is closely related to the horizontal well trajectory 1 / 4-1 / 3 obliquely penetrating the high permeability layer, Type 3: Rapid water flooding + rapid rise of water content is closely related to the horizontal well trajectory 1 / 3-2 / 3 well trajectory close to the high permeability layer, Type 4: Sudden water flooding + high water content slow rise is closely related to high viscosity oil, more than 2 / 3 of the horizontal well trajectory close to the high permeability layer or located above the high permeability layer, Type 5: Sudden water flooding + high water content rapid rise is usually the horizontal well is located in the fracture bottom water area and oil is lost during drilling. In terms of the difficulty of water control, Type 1> Type 2> Type 3> Type 4> Type 5, in terms of the remaining potential, it is necessary to combine the current production situation, mainly the production degree of the single well before water control. In general, the development effect of oil wells in type 1 is better, and water control is not needed at this stage. Due to the influence of fractures and natural bottom water, it is difficult to control the water of type 5 by artificial intervention, so it is not within the scope of this water control. On this basis, the oil wells with water content exceeding 80% and 90% in types 2, 3 and 4 are selected as the objects of high water-content well control. The main controlling factors and potential of water content increase of these high water-content wells are clarified by reservoir engineering analysis methods. Combined with the degree of geological reserve recovery as the residual potential indicator, the selected water-control oil wells are classified as follows:

[0046] (1) Horizontal oil wells with a water content greater than 90%, a geological reserve recovery rate less than 15%, and a well trajectory obliquely crossing a high permeability layer are classified as Class 1 water control objects.

[0047] (2) Horizontal oil wells with a water content of no more than 90%, a geological reserve recovery rate of less than 20%, and a well trajectory obliquely crossing a high permeability layer are regarded as Class 2 water control objects.

[0048] (3) Horizontal oil wells with a water content of no more than 90%, a proportion of the well trajectory in the high permeability layer greater than a set proportion, or a distance between the well trajectory and the high permeability layer less than a set distance are regarded as Class 3 water control objects.

[0049] That is, horizontal oil wells with a water content of no more than 90% and most of their well trajectories in high permeability layers or close to high permeability layers are regarded as Class 3 water control objects.

[0050] (4) Horizontal oil wells with a water content of no more than 90% and well trajectories above high permeability layers are classified as Class 4 water control objects.

[0051] The above four types of water control are ranked from easy to difficult, and the remaining potential is ranked from large to small, providing priority for subsequent regulation.

[0052] Step S12: Based on the comparison with the resistivity curve of the passing well, the preliminary identification results of the direction of the water flow channel and the remaining oil enrichment location are obtained, and the flooding degree of each water control object and the water saturation before water injection are clarified.

[0053] In step S11, several types and potential sizes of oil wells with high water content are identified, which can be considered in combination with identifying the direction of water flow channels and the remaining oil enrichment sites in step S12.

[0054] The passing well corresponding to each water control object is clearly defined. The passing well is a well that encounters the same oil reservoir and whose resistivity curve acquisition time is later than that of the corresponding water control object. The passing well is connected with the corresponding water control object in the oil reservoir.

[0055] Due to logging costs, logging data may only be collected once for the same well; if logging data is collected multiple times for the same horizontal oil well, the logging curves of the same well can also be compared.

[0056] A multi-dimensional three-dimensional water-flooded layer quantitative interpretation model based on cluster sample learning was established. The logging resistivity difference between the wells passing through the target reservoir and the wells before water injection in different time periods was used to study the water-flooding characteristics, clarify the water-flooding mode and the migration direction of the injected water. When making comparisons, the logging curves were transformed with reference to the stratification results of each well to ensure that the top and bottom surfaces of each layer of the new and old well curves were aligned.

[0057] When the resistivity difference between the new and old wells is more than 20%, it is determined that the layer is flooded. According to this standard, all the passing wells are analyzed, classified according to the flooding characteristics and the flooding mode is summarized. Combined with the plane distribution position of the high water-content wells in step S11, the analysis is performed to clarify the direction of the water flow advantage channel of these high water-content wells, the reasons and mechanisms of water content increase, and the degree of flooding in the flooded layer is realized from qualitative analysis to quantitative evaluation, and the flooding characteristics of the differentiated injection and production of horizontal wells under different main control factors are clarified. For example: in the oil reservoir with a high permeability layer at the top and relatively good physical properties of the injection well layer, the horizontal well development mode of top production and bottom residence, affected by the high permeability thief layer, the "double inverted water cone" flooding mode is the main mode between the injection and production well groups, and there are two main and secondary water flow channels. Affected by the well trajectory, the plane residual oil is unevenly distributed, and the vertical residual oil is enriched in the middle and lower part of a small layer. The high permeability layer is a channel for invalid and inefficient circulation of injected water. During the injection and production process, the injected water is easily concentrated in the horizontal wellbore near the high permeability layer.

[0058] Through step S12, preliminary identification results of the direction of the water flow channel and the remaining oil enrichment area are obtained, and the flooding degree of each water control object and the water saturation before water injection are clarified. However, these are only the values ​​of certain monitoring points and cannot fully support the judgment of the entire well area of ​​the water control object well.

[0059] Step S13: Based on the preliminary identification results and the monthly data of oil and water wells, the knowledge of the remaining oil-rich areas is updated through the fitting of the dynamic numerical model, and the classification and ranking of water control objects are adjusted in combination with the degree of flooding.

[0060] By means of numerical simulation, the monthly data of oil and water wells are loaded into the dynamic numerical model. Combined with the preliminary identification results obtained in step S12, the oil production, water content and pressure of the whole area and single well are fitted. At the same time, the saturation monitoring of passing well points at different times is also fitted. The remaining oil enrichment area of ​​the reservoir is clarified according to the fitting results; the intersection relationship between the horizontal section of the water control object and the high permeability layer and the remaining oil enrichment area is analyzed, and the classification and sorting of the water control objects are adjusted in combination with the degree of water flooding.

[0061] The water control objects of the high water-content wells screened out in step S11 are marked in the dynamic model, and the plane and profile distribution maps of the remaining oil of these wells are proposed from the model to clarify the remaining oil enrichment location. After a long period of water injection development, the high permeability layer has a high flushing multiple, and the high permeability layer and the next high permeability layer above the high permeability layer have a high degree of water flooding, while the lower layer system with a large difference in physical properties from the high permeability layer has a low degree of water flooding, a low degree of utilization, and a large potential for remaining oil, which is the main remaining oil enrichment location. Further confirm whether there is an intersection relationship between the remaining oil enrichment location, the high permeability layer and the horizontal section of the horizontal well. If all three have an intersection, the judgment in step 1 is retained as a Class 1 or Class 2 water control object, and Class 3 and Class 4 water control objects can also be optimized or adjusted or eliminated based on the result. For example: the trajectory of the horizontal well section penetrating the high permeability layer is less than 1 / 4 of the length of the horizontal section, and 1 / 2 of the well section is located in the low permeability part below the high permeability layer. The mining index also shows that the potential for tapping is large, which can be used as the key optimization and adjustment object.

[0062] In the above steps, the wells with water control potential are comprehensively determined. Next, the location of liquid accumulation in the wellbore of the study well is determined and the amount of liquid accumulation is calculated using theoretical calculation formulas.

[0063] Step S14: Determine the current amount of liquid accumulation of the water-controlled object based on its water saturation before water injection and injection and production data.

[0064] Usually in heterogeneous reservoirs, liquid accumulation is mainly concentrated in the part where the horizontal well section penetrates the high permeability layer, but this method is not very accurate. In the embodiment of this application, a horizontal well multi-stage production test interpretation model is adopted to accurately identify the water-seeping part, and then the horizontal well liquid accumulation theoretical formula is used to calculate the liquid accumulation volume of each single well at each moment. This formula takes the oil well as the center, supplies the injection volume to the water injection well, considers the influence of the flooding volume of the high permeability layer in the early stage and the discharge volume of the oil well during the treatment period, and derives the liquid accumulation surplus near the horizontal wellbore on the tth day. Based on a large amount of oil well treatment experience, when the liquid accumulation surplus is 1 / 2 or 2 / 3 of the original liquid accumulation volume, the water content has shown a significant downward trend. Due to differences in single wells, appropriate fine-tuning can be made according to the change trend. This formula can also calculate the discharge time at constant injection and production rates.

[0065] Specifically, determining the current amount of fluid accumulation of the water control object includes the following steps:

[0066] Step S141: determining the amount of accumulated liquid before water injection based on the water saturation of the water control object before water injection.

[0067] Based on the water saturation of the water control object before water injection, the amount of liquid accumulation before water injection is determined by the following formula (1):

[0068]

[0069] In formula (1), M1 represents the amount of liquid before water injection, m 3 ;

[0070] H represents the effective thickness of the hyperpermeable layer, m;

[0071] A represents the drainage area of ​​horizontal oil wells, A = (1 / 2) * oil and water well spacing * (1 / 2) * distance between adjacent oil wells, km 2 ;

[0072] Φ represents the average porosity of the high permeability layer, %;

[0073] Swi represents the water saturation before water injection, a decimal;

[0074] Swc represents irreducible water saturation, which is usually obtained by calibration of the oil-water relative permeability curve, a decimal;

[0075] Bwi represents the volume coefficient of formation water, which is provided by formation water experimental data or empirical formula calculation and is dimensionless.

[0076] Step S142: Determine the cumulative water injection volume according to the average injection volume, injection volume splitting coefficient and injection time of each injection well that has a communication relationship with the water control object.

[0077]

[0078] In formula (2): Mn Indicates the cumulative water injection volume, m 3 ;

[0079] t=1,2,……,n, n represents the number of time units included in the total production time (which can also be understood as the water injection time), and the unit of the time unit is day / week / month;

[0080] i represents the serial number of the injection well corresponding to the water control object, i=1,2...I;

[0081] P it It represents the injection volume splitting coefficient of the connected injection well i in the tth time unit, a decimal;

[0082] W it represents the average injection volume of the connected injection well i in the tth time unit, m 3 / d(or m 3 / week, or m 3 / moon).

[0083] Step S143: Determine the cumulative liquid production according to the average oil production, average water production and production time of the water-controlled object.

[0084]

[0085] In formula (3), N n Indicates the cumulative liquid production, m 3 ;

[0086] represents the average oil production in the t-th time unit, represents the average water production in the t-th time unit;

[0087] Boi represents the volume coefficient of crude oil.

[0088] Step S144: Add the accumulated liquid volume before water injection to the accumulated water injection volume and then subtract the accumulated liquid production volume to obtain the current accumulated liquid volume of the water control object.

[0089] D n =M+M n -N n (4)

[0090] In formula (4), D n Indicates the current amount of effusion, m 3 .

[0091] Step S15: Based on the adjusted classification and ranking of water control objects, formulate the implementation sequence of water control measures and water control measures for each water control object, determine the water production of the water control object after the implementation of the water control measures, and determine the ratio of the accumulated liquid volume to the water production volume as the predicted drainage time.

[0092] The water control measure is to adjust the work system.

[0093] Based on step S14, the amount of accumulated liquid near the current wellbore is calculated, and the corresponding working system adjustment scheme for oil and water well adjustment is used. When the water content of the oil well is high, there are four schemes: lowering the water injection volume, lowering the liquid production volume, lowering the water injection volume + lowering the liquid production volume, and lowering the water injection volume + raising the liquid production volume. For scenario 1: oil wells with rapid water content increase (monitoring water content every day) and high pressure, lowering the water injection volume + raising the liquid production volume is adopted. Scenario 2: oil wells with rapid water content increase and low pressure level, lowering the water injection volume + lowering the liquid production volume is adopted. Scenario 3: oil wells with rapid water content increase and medium pressure level are adopted. Lowering the water injection volume is adopted. Scenario 4: oil wells with rising water content and low pressure are adopted. The adjustment range of the oil well should consider the upper and lower limits of the electric pump oil well, and the water injection well should consider the influence of corrosion. The minimum water injection volume is not less than 100 barrels / day. It is best that the water injection volume should control the injection-production ratio of the current well group within 0.95. After selecting different water control measures, the liquid production of the oil well can be determined. At the same time, the water production can be calculated by testing the water content, and the ratio of the accumulated liquid volume to the water production can be determined as the predicted drainage time.

[0094] The water control method for water injection development of heterogeneous oil reservoirs provided in the first embodiment of the present invention, through the implementation of steps S11 to S15, analyzes the development rules and dynamic characteristics of high water-cut horizontal oil wells, diagnoses water flooding and identifies water flow channels, characterizes the distribution of residual oil, calculates wellbore liquid accumulation and drainage time, and designs and implements water control measures. The method provides a new water control method and process for high water-cut horizontal wells in heterogeneous oil reservoirs, thereby continuously controlling the water content of oil wells and increasing the oil production of single wells.

[0095] Since most horizontal wells are completed in open holes and the wellbore integrity is insufficient, the implementation cost of water plugging and profile control technology is high, the process is difficult, and the effective period of oil production is short. The water control method for water injection development of heterogeneous oil reservoirs provided in Example 1 of the present invention does not require any measures or construction, and does not increase additional operating costs. After diagnosing the residual oil-rich layer, the high-permeability layer liquid is eliminated and the low-permeability layer is utilized through reasonable adjustment of the oil and water well working system. Different adjustment strategies are used to fully tap the residual oil potential of high-water-content oil wells and improve the reservoir development effect. It is a new type of high-water-content horizontal well management method that can achieve "zero cost" quality and efficiency improvement in heterogeneous oil reservoirs.

[0096] In some embodiments, it also includes, for the water control object after the implementation of the water control measures, repeating step S14 on a weekly basis, determining the change in the amount of accumulated fluid, monitoring the change in water content, updating the predicted drainage time, and evaluating the water control effect; if the water control effect does not reach the set effect, modifying the current water control measures.

[0097] In some embodiments, the method further includes repeating steps S11 to S15 on a monthly basis, wherein the newly screened water control objects do not include horizontal oil wells for which water control measures have been taken.

[0098] After selecting the target wells for water control through steps one, two and three on a monthly basis, these wells are monitored on a weekly basis for changes in water content after regulation and control and for evaluating the water control effect. The calculation process of steps four and five is repeated to determine the instantaneous liquid accumulation and drainage time. In this process, it is necessary to instantly meet the four different scenarios and adjust the plan of step five in a timely manner, and then continue to observe the water control effect through single-well water content testing. The above are the steps for the subsequent implementation of the target wells for water control proposed in the previous month. When selecting and implementing water control objects in the next month, it is necessary to remove the water control objects of the previous month from step one, and then update the classification adjustment to determine whether there are new target wells for water control. If there are new target wells for water control, they will be processed according to steps two, three, four and five, and then the water control measures will be designed and implemented according to the weekly processing flow.

[0099] Embodiment 2

[0100] The second embodiment of the present invention provides a specific application of a water control method for water injection development in a heterogeneous oil reservoir, which is implemented in a heterogeneous carbonate reservoir in a certain oil field. The reservoir is developed in a top production and bottom injection mode with a horizontal well pattern. Figure 2 ), started water injection pilot test in 2012, and realized large-scale water injection development at the end of 2014. Affected by the high permeability layers developed in the whole area, the water content of oil wells increased rapidly to 40-60% after water injection, the comprehensive water content was 65.9%, the geological recovery rate was 13.2%, and the water content of 33 oil wells exceeded 80%, making it difficult to stabilize oil and control water.

[0101] As of February 2021, 54 wells have been drilled in the AD1 area, of which 13 have a water content greater than 90%, mainly located in the alternating test area and its south; 13 have a water content between 80% and 90%, located in the fracture area, test area and east side. 23 wells have been drilled in the AD2 area, of which 3 have a water content greater than 90%, 2 are located in the alternating test area; 2 have a water content between 80% and 90%, and 1 is located in the test area. 30 wells have been drilled in the AD4 area, of which 2 have a water content greater than 90%. See Figure 3 According to step S11, the objects waiting for high water content treatment and urgently in need of adjustment are sorted out.

[0102] 33 wells were selected from the three blocks of the above-mentioned typical oil reservoirs as the targets for high water-content well treatment, and the AD1 area was selected as a typical area. Through the analysis of the flooding characteristics of the passing wells in the vertical and horizontal directions, the method of step two was used to monitor the saturation changes of the typical horizontal injection and production well group after two and four years of water injection. It can be seen that: the high permeability layer Kh2-1-2L and the top of Kh2-2 are obviously flooded, the flooding degree of Kh2-3 is second, and the flooding of Kh2-1-2U varies due to the influence of position; after two years of water injection, the entire well section of the injection well is flooded, and after four years of water injection, the middle well points between the injection well and the production well, as well as the production well, are mainly flooded in Kh2-3 and the high permeability layer, Kh2-1-2U and the upper part of Kh2-2, while the flooding degree of kh2-2 is relatively low. Figure 4 From the distribution of horizontal production well trajectories, more than 75% of the oil well trajectories pass through high permeability layers or large sections of sub-high permeability layers above the high permeability layers. The flow patterns of injected water in these production wells are similar to those in the Figure 4 The proportion of oil wells with horizontal production well trajectories located in the middle and lower part of kh2-2 is only 23.5%, and most of them are unevenly distributed, which has little effect on the overall flow law of injected water.

[0103] The 18 extremely high water-cut wells selected above need to understand the reasons why the water content quickly rises to extremely high water content. They are classified according to the causes of high water content and three main causes are identified:

[0104] Category 1: 8 wells shut down and resumed production with water content exceeding 80% or even 90%

[0105] Category 2: 12 wells with periodic changes during the five-point alternating injection and production period

[0106] Category 3: 13 wells with increased water content due to the shutdown of surrounding oil wells

[0107] Therefore, the initial stage of water content increase is mainly affected by the main controlling factors. Under the current situation of high flooding degree of high permeability layer, the change of water content mainly depends on the matching relationship between the horizontal well trajectory and the high permeability layer, the injection and production intensity of surrounding injection wells, shut-in wells and other factors.

[0108] At present, the main controlling factors of high water-content oil wells (>90%) are high permeability layer + well trajectory. The well trajectory penetrates the high permeability layer and penetrates the high permeability layer multiple times, or is close to the high permeability layer. The water saturation near the oil well trajectory is relatively high, and the formed water flow dominant channel hinders the displacement of the surrounding residual oil. The causes of the three types of high water-content wells are analyzed in detail below (Table 1).

[0109] Table 1 Analysis of the causes of high water content after well shut-in and resumption of production

[0110]

[0111] Category 1: High water content after well shutdown and resumption of production

[0112] The focus of the analysis is on 7 wells that were shut down and resumed production in 2020 with a water content of over 90%. The main controlling factors are high permeability layers + well trajectories. The cumulative oil production is between 1.38 million and 2.27 million barrels. The tested water content has been basically stable for a period of time, exceeding 95%. The recovery rate of a single well is 10.9%-40.1%, and the recovery rate of a well group is 10.0%-35.0%.

[0113] Through comparative study of 26 shut-in wells and resumption of production, 15 wells resumed production in AD1 area, 3 wells resumed production in AD2 area in 2020, and 6 wells resumed production in AD4 area, the number of days of high water content maintenance is related to the well trajectory and water storage rate. The high single injection and cumulative injection volume during the shutdown period resulted in a high water storage rate. The well trajectory was located in an oil well that was relatively affected by the high permeability layer. The water content rose significantly after resumption of production, the high water content was maintained for a relatively long time, and the drainage and water control time was longer ( Figure 5 and Figure 6 ).

[0114] Category 2: Water content fluctuates and rises during the five-point method alternation

[0115] The alternating test area in the AD1 area mainly selected oil wells with a water content of about 80% before the test for alternation. This alternating mode will have a high water content point during the alternating process (Table 2).

[0116] Table 2 Water content fluctuation rising well data table during the five-point method alternation period

[0117]

[0118] Taking row AD1-11 as an example, the high water content point is before the alternating well opening and closing, which may be caused by the short adjustment cycle of oil wells and water wells. Figure 7 .

[0119] The same rule can be seen through numerical simulation. Five oil wells were shut down, but water injection wells were still injecting water. When the wells were opened, similar to the resumption of production of shut-in wells, water content surged. Later, as the water injected during shut-in was discharged, the water content began to decrease. The alternating injection and production of rows 9-13 in the AD1 area has been carried out for a year. The water control effect gradually deteriorated in the later period. Before the rotation, some wells showed an increase in water content, which indicates that an oblique channel has been formed. Figure 8 .

[0120] The third category of surrounding oil well shutdown impact

[0121] Recently, due to the shutdown of surrounding oil wells and the continuous injection of water wells, some wells have experienced water breakthrough in a short period of time. The main controlling factor of these wells is also the high permeability layer, and the well trajectories are close to the high permeability layer, which is greatly disturbed by the surrounding oil and water wells (Table 3).

[0122] Table 3 High water-cut wells caused by shutdown of surrounding oil wells

[0123]

[0124] For the above-mentioned high water-content well types, under the current condition of good pressure recovery, the adjustment strategy of lifting and lowering injection of some wells was implemented. The wellbore liquid accumulation and the drainage time under the current electric pump working system were calculated through step 4. The preliminary plan for single well adjustment was clarified through step 5. The effect of lifting and lowering injection was predicted on the numerical simulator ( Fig. 9 ). After each scheme was implemented for a period of time, the water content of the production wells was significantly improved, and the static pressure of the single well was the basic scheme > liquid lifting\reducing injection > liquid lifting + reducing injection, and the pressure drop was acceptable. At the same time, by lifting liquid and reducing injection, the flow lines of some oil wells can be improved, and the reserves in the middle and lower parts of Kh2-2 with lower oil saturation can be used to achieve the purpose of reducing water.

[0125] For the wells with high water content, the amount of liquid accumulated in the wellbore and the drainage time were calculated based on step 4, and the adjustment strategy of raising the liquid and reducing the injection was determined and implemented. Through the injection-production adjustment, 12 wells saw obvious results, and the drainage time to control the water content was 1.5 months to 4 months. The oil wells that did not see the effect were mainly affected by the fact that the well trajectory penetrated more high-permeability layers and the water injection wells were concentrated, requiring a longer drainage time. Specific implementation effect table 4.

[0126] Table 4 Water control effect of injection and production adjustment in high water-cut wells (four months after implementation)

[0127]

[0128]

[0129] As shown in the table above, 4 months after the implementation of the injection-production adjustment, 3 out of 7 wells with high water content after resumption of production saw obvious effects, and the water content of the other 4 wells also decreased slightly. For the high water content wells in the five-point alternating injection-production wells, 5 out of 7 wells saw obvious effects, and 2 wells did not see obvious effects. For the high water content wells caused by the closure of surrounding oil wells, the water content of 3 wells decreased significantly after half a month to three months of implementation, and there was no obvious change in 1 well. The treatment of these wells will be continuously tracked, and the effective period after treatment will be more than one and a half years as of March 2023.

[0130] Based on the inventive concept of the present invention, an embodiment of the present invention further provides a heterogeneous oil reservoir water injection development method, including controlling water during the heterogeneous oil reservoir water injection development process using the above-mentioned heterogeneous oil reservoir water injection development water control method.

[0131] Based on the inventive concept of the present invention, an embodiment of the present invention further provides a water control device for water injection development of a heterogeneous oil reservoir, the structure of which is as follows: Fig.10 As shown, including:

[0132] The water control object preliminary screening and classification module 101 is used to screen water control objects from horizontal oil wells in the oil reservoir, classify and sort them according to the positional relationship between the well trajectory and the high permeability layer and the water content and recovery degree included in the single well dynamic development data;

[0133] The flooding characteristic analysis module 102 is used to obtain preliminary identification results of the direction of the water flow channel and the remaining oil enrichment location based on the comparison with the resistivity curve of the passing well, and to clarify the flooding degree of each water control object and the water saturation before water injection;

[0134] The water control object classification and ranking optimization module 103 is used to update the knowledge of the remaining oil-enriched parts based on the preliminary identification results and the monthly data of oil and water wells through the fitting of dynamic numerical models, and adjust the classification and ranking of water control objects in combination with the flooding degree;

[0135] The liquid accumulation calculation module 104 is used to determine the current liquid accumulation of the water control object based on the water saturation before water injection and the injection and production data;

[0136] The water control measures formulation module 105 is used to formulate the order of implementation of water control measures and water control measures for each water control object based on the adjusted classification and ranking of water control objects, determine the water production of the water control object after the implementation of the water control measures, and determine the ratio of the accumulated liquid volume to the water production volume as the predicted drainage time. The water control measures are to adjust the work system.

[0137] In some embodiments, the water control object preliminary screening and classification module 101 screens out water control objects from horizontal oil wells in the reservoir according to the positional relationship between the well trajectory and the high permeability layer and the water cut and recovery degree included in the single well dynamic development data, and classifies and sorts them for:

[0138] According to the water cut and recovery degree included in the dynamic development data of a single well, a curve of water cut and recovery degree of a single well is drawn, and the water cut rise type of the horizontal oil wells in the reservoir is classified according to the characteristics of the curve, and the corresponding relationship between the water cut rise type and the influencing factors is clarified; according to the positional relationship and water cut of the well trajectory and the high permeability layer, on the basis of the classification results of the water cut rise type and the corresponding relationship between the water cut rise type and the influencing factors, water control objects are screened out from the horizontal oil wells in the reservoir, and classified and ranked in terms of the difficulty of regulation.

[0139] In some embodiments, the water control object preliminary screening and classification module 101, which screens out water control objects from horizontal oil wells in the oil reservoir, classifies them and sorts them by degree of difficulty of control, is used to:

[0140] Horizontal oil wells with a water cut greater than 80% are selected from the horizontal oil wells in the reservoir as water control objects; horizontal oil wells with a water cut greater than 90%, a geological reserve recovery rate less than 15%, and a well trajectory obliquely crossing a high permeability layer are selected as Class 1 water control objects; horizontal oil wells with a water cut of no more than 90%, a geological reserve recovery rate less than 20%, and a well trajectory obliquely crossing a high permeability layer are selected as Class 2 water control objects; horizontal oil wells with a water cut of no more than 90%, a proportion of the well trajectory in the high permeability layer greater than a set proportion, or a distance between the well trajectory and the high permeability layer less than a set distance are selected as Class 3 water control objects; horizontal oil wells with a water cut of no more than 90% and a well trajectory above the high permeability layer are selected as Class 4 water control objects; the water control of the above four types of water control objects is from easy to difficult, and the remaining oil potential is from large to small.

[0141] In some embodiments, the flooding feature analysis module 102 updates the knowledge of the remaining oil-enriched parts based on the preliminary identification results and the monthly data of oil and water wells through the fitting of the dynamic numerical model, and adjusts the classification and sorting of water control objects in combination with the flooding degree, for:

[0142] The monthly data of oil and water wells in the oil reservoir are loaded into the dynamic numerical model, and the oil production, water content and pressure of the whole area and single well are fitted in combination with the preliminary identification results, and the understanding of the remaining oil enrichment area is updated according to the fitting results; the intersection relationship between the horizontal section of the water control object and the high permeability layer and the remaining oil enrichment area is analyzed, and the classification and sorting of the water control objects are adjusted in combination with the degree of water flooding.

[0143] In some embodiments, the liquid accumulation calculation module 104 determines the current liquid accumulation based on the water saturation before water injection and the injection and production data of the water control object, and is used to:

[0144] The amount of liquid accumulated before water injection is determined based on the water saturation of the water control object before water injection; the cumulative water injection volume is determined based on the average injection volume, injection volume splitting coefficient and injection time of each injection well connected to the water control object; the cumulative liquid production is determined based on the average oil production, average water production and production time of the water control object; the current liquid accumulation volume of the water control object is obtained by adding the amount of liquid accumulated before water injection to the cumulative water injection volume and then subtracting the cumulative liquid production.

[0145] In some embodiments, the liquid accumulation volume calculation module 104 determines the liquid accumulation volume before water injection based on the water saturation before water injection of the water control object, including:

[0146] Based on the water saturation of the water control object before water injection, the amount of liquid accumulation before water injection is determined by the following formula:

[0147]

[0148] Where M represents the amount of liquid before water injection, H represents the effective thickness of the high permeability layer, A represents the oil drainage area, Φ represents the average porosity of the high permeability layer, Swi represents the water saturation before water injection, Swc represents the bound water saturation, and Bwi represents the volume coefficient of formation water.

[0149] In some embodiments, the liquid accumulation calculation module 104 determines the cumulative liquid production according to the average oil production, average water production and production time of the water control object, and is used to:

[0150] According to the average oil production, average water production and production time of the water control object, the cumulative liquid production is determined by the following formula:

[0151]

[0152] Where N n Indicates the cumulative liquid production. represents the average oil production in the t-th time unit, It represents the average water production in the tth time unit, t=1,2,…,n, n represents the number of time units included in the total production time, and Boi represents the volume coefficient of crude oil.

[0153] Regarding the device in the above embodiment, the specific manner in which each module performs operations has been described in detail in the embodiment of the method, and will not be elaborated here.

[0154] Based on the inventive concept of the present invention, an embodiment of the present invention further provides a computer storage medium, wherein the computer storage medium stores computer executable instructions, and when the computer executable instructions are executed by a processor, the above-mentioned water control method for water injection development of heterogeneous oil reservoirs is implemented.

[0155] Based on the inventive concept of the present invention, an embodiment of the present invention further provides a server, comprising: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor implements the above-mentioned water control method for water injection development of heterogeneous oil reservoirs when executing the program.

[0156] Unless otherwise specifically stated, terms such as processing, computing, calculating, determining, displaying, etc. may refer to the actions and / or processes of one or more processing or computing systems, or similar devices, which operate and convert data represented as physical (e.g., electronic) quantities within registers or memories of a processing system into other data similarly represented as physical quantities within memories, registers, or other such information storage, transmission, or display devices of the processing system. Information and signals may be represented using any of a variety of different techniques and methods. For example, data, instructions, commands, information, signals, bits, symbols, and chips mentioned throughout the above description may be represented by voltages, currents, electromagnetic waves, magnetic fields or particles, light fields or particles, or any combination thereof.

[0157] It should be understood that the specific order or hierarchy of steps in the disclosed process is an example of an exemplary method. Based on design preferences, it should be understood that the specific order or hierarchy of steps in the process can be rearranged without departing from the scope of protection of the present disclosure. The attached method claims present the elements of the various steps in an exemplary order and are not intended to be limited to the specific order or hierarchy described.

[0158] In the above detailed description, various features are grouped together in a single embodiment to simplify the disclosure. This method of disclosure should not be interpreted as reflecting an intention that an embodiment of the claimed subject matter requires more features than those set forth in each claim. On the contrary, as reflected in the appended claims, the invention is in a state of having less than all the features of the disclosed individual embodiments. Therefore, the appended claims are hereby expressly incorporated into the detailed description, with each claim standing on its own as a separate preferred embodiment of the invention.

[0159] Those skilled in the art will also appreciate that the various illustrative logic blocks, modules, circuits, and algorithmic steps described in conjunction with the embodiments herein can all be implemented as electronic hardware, computer software, or a combination thereof. In order to clearly illustrate the interchangeability between hardware and software, various illustrative components, blocks, modules, circuits, and steps are generally described above around their functions. Whether such functions are implemented as hardware or software depends on specific applications and the design constraints imposed on the entire system. A skilled person can implement the described functions in an alternative manner for each specific application, but such implementation decisions should not be interpreted as departing from the scope of protection of the present disclosure.

[0160] The steps of the method or algorithm described in conjunction with the embodiments herein may be directly embodied as hardware, a software module executed by a processor, or a combination thereof. The software module may be located in a RAM memory, a flash memory, a ROM memory, an EPROM memory, an EEPROM memory, a register, a hard disk, a mobile disk, a CD-ROM, or any other form of storage medium well known in the art. An exemplary storage medium is connected to the processor so that the processor can read information from the storage medium and can write information to the storage medium. Of course, the storage medium may also be an integral part of the processor. The processor and the storage medium may be located in an ASIC. The ASIC may be located in a user terminal. Of course, the processor and the storage medium may also be present in a user terminal as discrete components.

[0161] For software implementation, the techniques described in this application can be implemented with modules (e.g., procedures, functions, etc.) that perform the functions described in this application. These software codes can be stored in a memory unit and executed by a processor. The memory unit can be implemented within the processor or outside the processor. In the latter case, it is coupled to the processor in a communication manner via various means, which are well known in the art.

[0162] The above description includes examples of one or more embodiments. Of course, it is impossible to describe all possible combinations of components or methods for describing the above embodiments, but it should be recognized by those skilled in the art that the various embodiments can be further combined and arranged. Therefore, the embodiments described herein are intended to cover all such changes, modifications and variations that fall within the scope of protection of the appended claims. In addition, with respect to the term "comprising" used in the specification or claims, the word is covered in a manner similar to the term "including", just as "including," explained as a transitional word in the claims. In addition, any term "or" used in the specification of the claims is intended to represent "non-exclusive or". The terms "first", "second", and "third" are used for descriptive purposes only and cannot be understood as indicating or implying relative importance.

Claims

1. A water control method for water injection development of heterogeneous oil reservoirs, characterized in that: include: Step S11, selecting water control objects from horizontal oil wells in the oil reservoir, classifying and sorting them according to the positional relationship between the well trajectory and the high permeability layer and the water content and recovery degree included in the single well dynamic development data; Step S12, based on the comparison with the resistivity curve of the passing well, the preliminary identification results of the water flow channel direction and the remaining oil enrichment position are obtained, and the flooding degree of each water control object and the water saturation before water injection are clarified; Step S13, based on the preliminary identification results and the monthly data of oil and water wells, the knowledge of the remaining oil-rich parts is updated through the fitting of the dynamic numerical model, and the classification and ranking of the water control objects are adjusted in combination with the flooding degree; Step S14, determining the current amount of liquid accumulation of the water control object based on the water saturation before water injection and the injection and production data; Step S15, based on the adjusted classification and ranking of water control objects, formulate the implementation order of water control measures and water control measures for each water control object, determine the water production of the water control object after the implementation of the water control measures, and determine the ratio of the accumulated liquid volume to the water production volume as the predicted drainage time. The water control measure is to adjust the work system.

2. The method according to claim 1, characterized in that Also includes: For the water control object after the water control measures are implemented, step S14 is repeatedly performed on a weekly basis to determine the change in the amount of accumulated fluid, monitor the change in the water content, update the predicted drainage time, and evaluate the water control effect; If the water control effect does not reach the set effect, modify the current water control measures.

3. The method according to claim 2, characterized in that Also includes: Steps S11 to S15 are repeatedly performed on a monthly basis, and the newly screened water control objects do not include horizontal oil wells for which water control measures have been taken.

4. The method according to claim 1, characterized in that: The water control objects are selected from the horizontal oil wells in the oil reservoir according to the positional relationship between the well trajectory and the high permeability layer and the water content and recovery degree included in the single well dynamic development data, and classified and sorted, including: Draw a curve of water cut and recovery degree of a single well based on the water cut and recovery degree included in the dynamic development data of a single well, classify the water cut rise type of the horizontal oil wells in the reservoir according to the characteristics of the curve, and clarify the corresponding relationship between the water cut rise type and the influencing factors; According to the positional relationship between the well trajectory and the high permeability layer and the water content, on the basis of the classification results of water-cut rise types and the correspondence between water-cut rise types and influencing factors, water control objects are screened out from the horizontal oil wells in the reservoir, classified and ranked in terms of difficulty of control.

5. The method according to claim 4, characterized in that The water content rising types include water content rising slowly, rapid flooding and high water content rising slowly, rapid flooding and water content rising quickly, sudden flooding and high water content rising slowly, and violent flooding and high water content rising quickly. The influencing factors include high permeability layers, fractures and cracks, high-viscosity oil, bottom water and horizontal well trajectories.

6. The method according to claim 4, characterized in that The water control objects are selected from the horizontal oil wells in the oil reservoir, and classified and ranked according to the degree of difficulty of control, including: Horizontal oil wells with a water content greater than 80% are selected from the horizontal oil wells in the oil reservoir as water control objects; Horizontal oil wells with a water content greater than 90%, a geological reserve recovery rate less than 15%, and a well trajectory obliquely crossing a high-permeability layer are considered as Class 1 water control objects; Horizontal oil wells with a water content of no more than 90%, a geological reserve recovery rate of less than 20%, and a well trajectory obliquely crossing a high-permeability layer are considered as Class 2 water control objects; Horizontal oil wells with a water content of no more than 90%, a proportion of the well trajectory in the high permeability layer greater than a set proportion, or a distance between the well trajectory and the high permeability layer less than a set distance are regarded as Class 3 water control objects; Horizontal oil wells with water cut not more than 90% and well trajectory above the high permeability layer are regarded as Class 4 water control objects; The water control of the above four types of water control objects increases from easy to difficult, and the remaining oil potential increases from large to small.

7. The method according to claim 1, characterized in that The passing well is a well drilled into the oil reservoir and whose resistivity curve is collected later than the corresponding water control object. The passing well is connected with the corresponding water control object in the oil reservoir.

8. The method according to claim 1, characterized in that Based on the preliminary identification results and the monthly data of oil and water wells, the understanding of the remaining oil-rich parts is updated through the fitting of the dynamic numerical model, and the classification and ranking of water control objects are adjusted in combination with the degree of flooding, including: Loading monthly data of oil and water wells in the oil reservoir into the dynamic numerical model, fitting the oil production, water content and pressure of the whole area and single well in combination with the preliminary identification results, and updating the understanding of the remaining oil enrichment location according to the fitting results; The intersection relationship between the horizontal section of the water control object and the high permeability layer and the remaining oil-rich area is analyzed, and the classification and sorting of the water control objects are adjusted in combination with the degree of flooding.

9. The method according to claim 1, characterized in that: The method of determining the current amount of liquid accumulation based on the water saturation before water injection and the injection and production data of the water control object includes: Determine the amount of liquid accumulation before water injection based on the water saturation of the water control object before water injection; Determine the cumulative water injection volume according to the average injection volume, injection volume splitting coefficient and injection time of each injection well connected to the water control object; Determine the cumulative liquid production based on the average oil production, average water production and production time of the water control object; The current amount of liquid accumulation in the water-controlled object is obtained by adding the amount of liquid accumulation before water injection to the cumulative amount of water injection and then subtracting the cumulative amount of liquid production.

10. The method according to claim 9, characterized in that The method of determining the amount of accumulated liquid before water injection based on the water saturation of the water control object before water injection comprises: Based on the water saturation of the water control object before water injection, the amount of liquid accumulation before water injection is determined by the following formula (1): In formula (1), M represents the amount of liquid before water injection, H represents the effective thickness of the high permeability layer, A represents the oil drainage area, Φ represents the average porosity of the high permeability layer, Swi represents the water saturation before water injection, Swc represents the bound water saturation, and Bwi represents the volume coefficient of formation water.

11. The method according to claim 9, characterized in that Determining the cumulative liquid production according to the average oil production, average water production and production time of the water control object includes: According to the average oil production, average water production and production time of the water control object, the cumulative liquid production is determined by the following formula (2): In formula (2), N n Indicates the cumulative liquid production. represents the average oil production in the t-th time unit, It represents the average water production in the tth time unit, t=1,2,…,n, n represents the number of time units included in the total production time, and Boi represents the volume coefficient of crude oil.

12. A water flooding development method for a heterogeneous oil reservoir, characterized in that: The method comprises controlling water by using any method of claims 1 to 11 during water injection development of heterogeneous oil reservoirs.

13. A water control device for water injection development of heterogeneous oil reservoirs, characterized in that: The device comprises: The module for preliminary screening and classification of water control objects is used to screen out water control objects from horizontal oil wells in the reservoir, classify and sort them according to the positional relationship between the well trajectory and the high permeability layer and the water content and recovery degree included in the dynamic development data of a single well; The water flooding feature analysis module is used to obtain preliminary identification results of the direction of the water flow channel and the remaining oil enrichment site based on the comparison with the resistivity curve of the passing well, and to clarify the degree of water flooding of each water control object and the water saturation before water injection; A water control object classification and ranking optimization module is used to update the knowledge of the remaining oil-enriched parts based on the preliminary identification results and the monthly data of oil and water wells through the fitting of dynamic numerical models, and adjust the classification and ranking of water control objects in combination with the degree of flooding; The liquid accumulation calculation module is used to determine the current liquid accumulation of the water control object based on its water saturation before water injection and injection and production data; The water control measures formulation module is used to formulate the order of implementation of water control measures and water control measures for each water control object based on the adjusted classification and ranking of water control objects, determine the water production of the water control object after the implementation of the water control measures, and determine the ratio of the accumulated liquid volume to the water production volume as the predicted drainage time. The water control measures are to adjust the work system.

14. A computer storage medium, characterized in that: The computer storage medium stores computer executable instructions, and when the computer executable instructions are executed by the processor, the water control method for water injection development of a heterogeneous oil reservoir as claimed in any one of claims 1 to 11 is implemented.

15. A server, characterized in that: include: A memory, a processor, and a computer program stored in the memory and executable on the processor, wherein when the processor executes the program, the water control method for water injection development of a heterogeneous oil reservoir as claimed in any one of claims 1 to 11 is implemented.

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