A method, device and related equipment for predicting production performance of a target well

Abstract

This invention discloses a method, apparatus, and related equipment for predicting the reservoir production dynamics of a target well. The method includes: determining the average production rate of the target area based on the initial production rate of at least one well within the target area; correcting the average production rate of the target area based on the static parameters of the target well to obtain the initial production rate of the target well; determining the overall water cut of the target area based on the water production and production rate of all wells in the target area; determining the decline parameters of the target area based on the daily oil production and production months of each well; and constructing a reservoir production dynamics curve for the target well using the initial production rate of the target well, the overall reservoir water cut of the target area, and the decline parameters of the target area. This invention combines the influence of the static parameters of the target well on the production dynamics curve, thereby establishing a dynamic and static combined target well reservoir production dynamics curve, effectively improving the completeness and subdivision of the production dynamics curve, and enhancing the accuracy of the target well prediction.

Description

Technical Field

[0001] This invention relates to the field of oil and gas field development technology, and in particular to a method, apparatus and related equipment for predicting the production dynamics of a target well reservoir. Background Technology

[0002] In oilfield development, production forecasting is necessary for planned infill wells or layer-replacement wells. Typically, two methods are used to predict the production performance of target wells: numerical simulation and typical production curves. Numerical simulation, when a numerical model is available, offers advantages such as convenience, speed, ease of implementation, and low cost. However, without a numerical model, both geological and numerical models are required, which is complex and time-consuming, negating the aforementioned advantages. Therefore, in the absence of a numerical model for the target area, using typical production curves from a single well to predict the production performance of new or layer-replacement wells is the preferred method. Summary of the Invention

[0003] The inventors discovered during practical application that current methods for predicting production effects using typical curves usually consider dynamic parameters such as the initial production capacity and decline rate of old wells, but neglect static parameters such as reservoir thickness, reservoir permeability, and porosity. However, the static parameters of the target area can be obtained during reservoir development. Therefore, when using typical curves that only consider dynamic parameters for prediction, given the known static characteristics of the reservoir, the method suffers from insufficient detail in the typical curves due to the general nature of the parameters considered. This results in inaccurate prediction results, inevitably leading to errors compared to future production patterns, and limiting its application scope.

[0004] In view of the above problems, the present invention is proposed to provide a method, apparatus and related equipment for predicting the production dynamics of a target well reservoir that overcomes or at least partially solves the above problems.

[0005] In a first aspect, embodiments of the present invention provide a method for predicting the production dynamics of a target well reservoir, which may include:

[0006] The average production rate of the target area is determined based on the initial production rate of at least one single well within the target area.

[0007] Based on the static parameters of the target well, the average production rate of the target area is corrected to obtain the initial production rate of the target well;

[0008] Based on the water production and fluid production of all single wells in the target area, the overall water cut of the reservoir in the target area is determined;

[0009] Based on the daily oil production and number of months of production of the single well, the decline parameters of the target area are determined;

[0010] The reservoir production dynamic curve of the target well is constructed using the initial production rate of the target well, the overall water cut of the reservoir in the target area, and the decreasing parameters of the target area.

[0011] Optionally, before determining the average liquid production rate of the target area, the process may further include:

[0012] Determine the weight of the impact of at least one of the aforementioned single wells on the production dynamics of the target area.

[0013] Optionally, determining the weight of the impact of at least one of the single wells on the production dynamics of the target area may include:

[0014] Based on the expected production time of the target well and the production time of the single well, determine the total production time of the single well when the target well begins production;

[0015] The weight of a single well is determined by inversely weighting the total production time of the single well.

[0016] Optionally, determining the average liquid production rate of the target area may include:

[0017] The average production of the target area is determined by weighted averaging based on the weight of each well and its initial production.

[0018] Optionally, before determining the weight of the impact of at least one of the single wells on the production dynamics of the target area, the process may further include:

[0019] The individual wells included in the target area are screened, and those that meet at least one of the following conditions are removed: wells that are in a state of shutdown, wells in a state of abnormal production, and wells with a weight less than a preset weight threshold.

[0020] Optionally, the static parameters may include at least one of the following: effective thickness, permeability, porosity, and fluid viscosity.

[0021] Optionally, the step of correcting the average production rate of the target area based on the static parameters of the target well may include:

[0022] The average value of the static parameter within the target area is determined based on at least one static parameter from at least one of the single wells.

[0023] Based on the static parameters of the target well and the average value of those static parameters, determine the correction factor for the static parameters;

[0024] The average liquid production rate of the target area is corrected by a correction factor for at least one static parameter.

[0025] Optionally, determining the decline parameters of the target area based on the daily oil production and number of production months of the single well may include:

[0026] The average daily oil production per well is determined based on the daily oil production of at least one well within the target area and the number of months of production.

[0027] Based on the fitting relationship between the average daily oil production per well and the number of production months, the decreasing parameters of the target area are determined;

[0028] The decreasing parameters include: decreasing rate, decreasing index, and decreasing type.

[0029] Secondly, embodiments of the present invention provide a device for predicting the production dynamics of a target well reservoir, which may include:

[0030] An average production rate determination module is used to determine the average production rate of the target area based on the initial production rate of at least one single well within the target area.

[0031] The correction module is used to correct the average production rate of the target area based on the static parameters of the target well, so as to obtain the initial production rate of the target well.

[0032] The reservoir comprehensive water cut determination module is used to determine the comprehensive water cut of the target area based on the water production and fluid production of all single wells in the target area;

[0033] The decreasing parameter determination module is used to determine the decreasing parameters of the target area based on the daily oil production and number of production months of the single well;

[0034] The module is used to construct the reservoir production dynamic curve of the target well based on the initial production of the target well, the comprehensive water cut of the reservoir in the target area, and the decreasing parameters of the target area.

[0035] Optionally, the device may also include: a weight determination module and a filtering module;

[0036] The weight determination module is used to determine the weight of the impact of at least one of the single wells on the production dynamics of the target area;

[0037] The filtering module is used to filter the individual wells included in the target area and remove individual wells that meet at least one of the following conditions: individual wells that are in a state of shutdown, individual wells in a state of abnormal production, or individual wells whose weight is less than a preset weight threshold.

[0038] Thirdly, in this embodiment of the invention, a computer-readable storage medium is provided, on which a computer program is stored, which, when executed by a processor, implements the method for predicting the production dynamics of a target well reservoir as described in the first aspect.

[0039] Fourthly, in this embodiment of the invention, a computer device is provided, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the program, it implements the method for predicting the production dynamics of a target well reservoir as described in the first aspect.

[0040] The beneficial effects of the above-mentioned technical solutions provided in the embodiments of the present invention include at least the following:

[0041] This invention discloses a method, apparatus, and related equipment for predicting reservoir production dynamics of a target well. The method includes: determining the average production of the target area based on the initial production of at least one well within the target area; correcting the average production of the target area based on the static parameters of the target well to obtain the initial production of the target well; determining the comprehensive water cut of the target area reservoir based on the water production and production of all wells in the target area; determining the decline parameters of the target area based on the daily oil production and production months of each well; and constructing a reservoir production dynamics curve of the target well using the initial production of the target well, the comprehensive water cut of the target area reservoir, and the decline parameters of the target area. In this embodiment of the invention, by using dynamic parameters such as the initial production rate, decline parameters, and comprehensive water cut of old wells in the target area, combined with the influence of static parameters of reservoir properties on the production dynamic curve, a dynamic-static combined production dynamic curve for the target well reservoir is established. This effectively improves the completeness and subdivision of the production dynamic curve, enhances the accuracy of the prediction effect of the target well, and broadens the application scenarios of production dynamic curve prediction. It has superior positive significance for improving reservoir development.

[0042] Other features and advantages of the invention will be set forth in the description which follows, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures particularly pointed out in the written description, claims, and drawings.

[0043] The technical solution of the present invention will be further described in detail below with reference to the accompanying drawings and embodiments. Attached Figure Description

[0044] The accompanying drawings are provided to further illustrate the invention and form part of the specification. They are used in conjunction with embodiments of the invention to explain the invention and do not constitute a limitation thereof. In the drawings:

[0045] Figure 1 This is a flowchart illustrating the method for predicting the production dynamics of a target well reservoir provided in an embodiment of the present invention.

[0046] Figure 2 This is a flowchart illustrating a specific method for predicting the production dynamics of a target well reservoir provided in an embodiment of the present invention.

[0047] Figure 3 This is a flowchart illustrating the implementation of step S21 in an embodiment of the present invention;

[0048] Figure 4 This is a flowchart illustrating the implementation of step S23 in an embodiment of the present invention.

[0049] Figure 5 This is an example of the production dynamic curve before the initial liquid production was corrected using static parameters in an embodiment of the present invention;

[0050] Figure 6 This is an example of a production dynamic curve after correcting the initial liquid production using static parameters, provided in an embodiment of the present invention.

[0051] Figure 7 This is a diagram showing the relative positions of wells M63 and M48 in an example provided in this embodiment of the invention.

[0052] Figure 8 This is a schematic diagram of the production dynamics of well M48 provided in an embodiment of the present invention;

[0053] Figure 9 This is a schematic diagram of the production dynamics of well M63 provided in an embodiment of the present invention;

[0054] Figure 10 This is a schematic diagram of the structure of the target well reservoir production dynamic prediction device provided in an embodiment of the present invention. Detailed Implementation

[0055] Exemplary embodiments of the present disclosure will now be described in more detail with reference to the accompanying drawings. While exemplary embodiments of the present disclosure are shown in the drawings, it should be understood that the present disclosure may be implemented in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the disclosure to those skilled in the art.

[0056] This invention provides a method for predicting the production dynamics of a target well reservoir. This method utilizes the production dynamics characteristics of a single well in the target area, namely, by analyzing the initial production volume, decline pattern, and overall water cut of the reservoir at the time of production of a single well that has been put into production, a reservoir production dynamic curve under water cut conditions in the target area is constructed. Then, the initial production volume of the target area is corrected according to the static parameters of the target well, thereby obtaining the reservoir production dynamic curve of the target well.

[0057] Reference Figure 1 As shown, the method may include the following steps:

[0058] Step S11: Determine the average production rate of the target area based on the initial production rate of at least one single well within the target area.

[0059] This step involves statistically analyzing the initial production rates of individual wells within the target area. The average production rate of the target area can be calculated using a weighted average method. The average production rate of the target area represents the initial production level of the reservoir within that area. In this embodiment of the invention, the initial production rate of the target area is used as an important data point for constructing the production dynamic curve of the target well.

[0060] The target area mentioned above refers to the area formed by the same oil and gas reservoir within a preset area centered on the target well. In this embodiment of the invention, the target well refers to an oil well planned for production in the same oil and gas reservoir. This oil well can be a new well for infill drilling or a well for which a layer replacement measure is taken during the production process of an already produced well.

[0061] Step S12: Based on the static parameters of the target well, correct the average production rate of the target area to obtain the initial production rate of the target well.

[0062] In this embodiment of the invention, the initial production rate of the target area can be obtained through step S11. This is because the initial production rate of the target area is related to the static parameters of the average reservoir properties of the target area, and the initial production rate of the target well is also affected by the reservoir properties at the location of the target well. Therefore, the inventors of this embodiment innovatively propose to use the static parameters of the reservoir properties of the target well to correct the initial production rate of the target area, that is, to fully consider the influence of dynamic parameters and static parameters on the target well to determine the initial production rate of the target well, and thus accurately construct the production dynamic curve of the target well.

[0063] Step S13: Determine the overall water cut of the oil reservoir in the target area based on the water production and fluid production of all single wells in the target area.

[0064] In this embodiment of the invention, the overall reservoir water cut of the target area can be obtained by weighted averaging. Since the reservoirs within a target area are interconnected and dynamic, the overall reservoir water cut of all individual wells within the target area should be approximately the same. Therefore, when constructing the prediction curve, the overall reservoir water cut of the target area can be used to determine the oil production capacity of the target wells. That is, the overall reservoir water cut of the target area is determined by using the ratio of water production to fluid production of all exploited individual wells.

[0065] Step S14: Determine the decline parameters of the target area based on the daily oil production and production months of a single well.

[0066] Within the same target area, the oil production decline patterns among individual wells should be similar. In this embodiment of the invention, the decline parameter of the target well is characterized by using the average decline parameter of the target area. Specifically, a relationship curve between daily oil production and production months is constructed using the daily oil production and production months of the exploited individual wells in the target area, and then the decline parameter of this curve is calculated.

[0067] Step S15: Construct the reservoir production dynamic curve of the target well using the initial production of the target well, the comprehensive water cut of the target area, and the decreasing parameters of the target area.

[0068] By using the initial production rate of the target well obtained in step S12, the comprehensive water cut of the target area obtained in step S13, and the decreasing parameters of the target area obtained in step S14, the reservoir production dynamic curve of the target well can be constructed. For example, the daily oil production and cumulative oil production of the target well can be predicted using the Alps decreasing formula.

[0069] It should be noted that the initial production volume, reservoir water cut, and production dynamic curve construction using the decline parameters in the above steps of this embodiment are independent data, and therefore there is no specific order in which they are acquired. Steps S13 and S14 can be executed first, or steps S11 and S12 can be executed first, or they can be executed simultaneously. This embodiment of the invention does not impose any specific limitations on this.

[0070] In this embodiment of the invention, by using dynamic parameters such as the initial production rate, decline parameters, and comprehensive water cut of old wells in the target area, combined with the influence of static parameters of reservoir properties on the production dynamic curve, a dynamic-static combined production dynamic curve for the target well reservoir is established. This effectively improves the completeness and subdivision of the production dynamic curve, enhances the accuracy of the prediction effect of the target well, and broadens the application scenarios of production dynamic curve prediction. It has superior positive significance for improving reservoir development.

[0071] Furthermore, the invention is highly practical and can be widely applied to reservoir engineering evaluations such as new project evaluation, existing project research, extension, and self-evaluation. It can improve the accuracy and rationality of prediction results, providing more accurate development prediction data for subsequent drilling, oil production, surface, and economic aspects. At the same time, it can save research time for related research stages, resulting in significant economic benefits.

[0072] In a specific embodiment, n wells have already been put into production within the target area centered on the target well. Specific parameters of the n wells are obtained through data analysis, such as their permeability as k1, k2, ..., k... n The effective thicknesses of the n wells are h1, h2, ..., h n The initial production rates of n wells put into production are Ql1, Ql2, ..., Qln .

[0073] Reference Figure 2 As shown, the method for predicting the production dynamics of a target well reservoir provided in this embodiment of the invention may include the following steps:

[0074] Step S21: Determine the weight of the impact of at least one single well in the target area on the production dynamics of the target well.

[0075] When constructing the production dynamic curve of the target well, the inventors fully considered that the production dynamic curve of the target well is affected by the surrounding wells that have already been put into production and the production time of those wells. Furthermore, the longer the production time of a single well, the smaller its impact on the target well. Since the production times of n wells differ, their reference value to the target well also differs. In this invention, the weight is obtained using an inverse time weighting method, meaning the weight is inversely proportional to the production time of the wells already in production; the longer the production time, the smaller the weight.

[0076] Specifically, the determination of single-well weight refers to Figure 3 As shown, the following steps may be included:

[0077] Step S301: Based on the expected production time of the target well and the production time of a single well, determine the total production time of a single well when the target well begins production.

[0078] Step S302: Perform time-inverse weighting on the total production time of a single well to determine the weight of the single well.

[0079] The above steps can be expressed by formula (1) as follows:

[0080] ω i =(tt) 0i ) -u Formula (1)

[0081] Where t is the expected production time of the target well, in months;

[0082] t 0i This refers to the production time of a single well, specifically the production time of the i-th well within the target area, expressed in months.

[0083] u is a time power parameter, which characterizes the degree to which the weighting coefficient decreases as time increases. When the value of u is larger, the weight of a single well with a smaller time difference will be higher, that is, the influence on the aforementioned time difference will be greater. In the embodiments of the present invention, the time power parameter u can take values ​​of 1, 2, 4, etc., and the inventors generally take a value of 2 based on experience.

[0084] Step S22: Determine the average production rate of the target area based on the initial production rate of at least one single well within the target area.

[0085] This step can refer to step S11 above. Specifically, based on the weight of the single well and the initial production of the single well obtained in step S21, the average production of the target area is determined by weighted averaging. The average production of the target area is expressed by formula (2) as follows:

[0086]

[0087] Where Qlave is the average liquid production in the target area (ave is an abbreviation for average, meaning average);

[0088] This step determines the average production rate of the target area by multiplying the weight of a single well by its initial production rate.

[0089] Step S23: Based on the static parameters of the target well, correct the average production rate of the target area to obtain the initial production rate of the target well.

[0090] This step can refer to step S12 above. Since there are certain differences between the static parameters of the target well and the static parameters of the target area, the inventors of this application have innovatively introduced a method of using static parameter correction to correct the average production of the target area.

[0091] Specifically, the static parameters of the target well are the parameters of the reservoir properties of the target well, which may include at least one of the following: effective thickness, permeability, porosity, and fluid viscosity.

[0092] Among them, effective thickness refers to the thickness of the portion of the oil reservoir with industrial oil production capacity, that is, the thickness of the reservoir with movable oil in an industrial oil well; permeability refers to the ability of rock to allow fluid to pass through under a certain pressure difference, and is a parameter characterizing the ability of soil or rock itself to conduct liquid; porosity refers to the ratio of the sum of the volumes of interconnected pores that allow fluid to flow under normal pressure conditions to the total volume of the rock sample, expressed as a percentage; fluid viscosity refers to the flow of fluids in different planes but parallel to each other, with the same area "A", separated by a distance "dx", and flowing in the same direction at different velocities "V1" and "V2". Newton assumed that the force maintaining these different flow velocities is proportional to the relative velocity or velocity gradient of the fluids, that is: τ=ηdv / dx=ηD (Newton's formula), where η is related to the material properties and we call it "viscosity".

[0093] The method of correcting the static parameters described above in the embodiments of the present invention can be referred to as follows. Figure 4 As shown, the specific steps may include:

[0094] Step S401: Determine the average value of the static parameter in the target area based on at least one static parameter from at least one single well.

[0095] In this embodiment of the invention, the effective thickness and permeability of the aforementioned n wells are used for illustration. For example, the permeability of the n wells are k1, k2, ..., k n The effective thicknesses of the n wells are h1, h2, ..., h n The effective thickness of the reservoir in the target area, *have*, can be obtained by weighted averaging, as shown in formula (3). The reservoir permeability, *kave*, can also be obtained, as shown in formula (4). Formulas (3) and (4) are as follows:

[0096]

[0097]

[0098] Step S402: Determine the correction coefficient of the static parameter based on the static parameter of the target well and the average value of the static parameter.

[0099] The effective thickness have and permeability kave of the target reservoir obtained through step S401 above, together with the effective thickness and permeability in the static parameters of the target well, can yield the effective thickness adjustment coefficient ω as shown in formula (5). h And the permeability correction coefficient ω as shown in formula (6) k The details are as follows:

[0100] ω h =h t / h ave Formula (5)

[0101] ω k =k t / k ave Formula (6)

[0102] Step S403: Correct the average production rate of the target area using a correction factor for at least one static parameter. The initial production rate of the target well after correction is shown in formula (7):

[0103]

[0104] Step S24: Determine the overall water cut of the oil reservoir in the target area based on the water production and fluid production of all single wells in the target area.

[0105] This step can refer to step S13 above. Specifically, the overall water cut of the target reservoir can be obtained by comparing the ratio of water production to fluid production of all exploited wells in the target area. Assuming the overall water cut of the target reservoir is wct, then the oil content of the target reservoir is ω. wct =1-wct.

[0106] The oil production capacity of the target well is shown in formula (8):

[0107]

[0108] Step S25: Determine the decline parameters of the target area based on the daily oil production and production months of a single well.

[0109] This step can be referred to as step S14 above. For details, please refer to [link / reference]. Figure 5 As shown, the following steps may be included:

[0110] Step S501: Determine the average daily oil production per well based on the daily oil production of at least one well in the target area and the number of production months.

[0111] In this step, the daily oil production of n wells is summed according to the number of production months, and the average daily oil production per well is calculated. The curve showing the relationship between the average daily oil production per well and the number of production months is then plotted.

[0112] Step S502: Based on the fitting relationship between the average daily oil production per well and the number of production months, determine the decline parameters of the target area; wherein, the decline parameters include: decline rate, decline index and decline type.

[0113] This step involves fitting the curve of the relationship between the average daily oil production per well and the number of months of production to obtain the decline parameters of the target area. The decline type in the decline parameters can be matched with reference to Table 1 below.

[0114] Table 1

[0115]

[0116]

[0117] Step S26: Construct the reservoir production dynamic curve of the target well using the initial production of the target well, the comprehensive water cut of the target area, and the decreasing parameters of the target area.

[0118] This step can refer to step S15 above, that is, substituting the initial production of the target well, the comprehensive water cut of the target area reservoir, and the decline parameters of the target area into the Alps decline formula to obtain the daily oil production and cumulative oil production of the target well, that is, to obtain the reservoir production dynamic curve of the target well. The specific construction process will not be described in detail in this embodiment.

[0119] In an optional embodiment, before determining the weight of the impact of at least one single well on the production dynamics of the target well, i.e. before analyzing the single-well data of the target area, the method may further include:

[0120] The individual wells within the target area are screened, and those that meet at least one of the following conditions are removed: wells that are out of production, wells with abnormal production status, or wells with a weight less than the preset weight threshold.

[0121] This invention performs noise reduction processing on the original data, resulting in a production dynamic curve that better matches actual needs.

[0122] In this embodiment of the invention, by combining dynamic and static parameters, and fully considering the influence of parameters such as reservoir properties in the target area on typical production dynamic curves, a method for predicting typical curves of a single well by combining dynamic and static parameters is established. This method can effectively improve the completeness and subdivision of the typical curve library, enhance the accuracy of single-well prediction results, and broaden the application scenarios of typical curve prediction. At the same time, this method provides a more accurate prediction approach for comprehensive oilfield adjustments.

[0123] The following examples in the embodiments of the present invention are provided to demonstrate the beneficial effects of this application. The specific data are original data from actual production and were not disclosed before this patent application.

[0124] Taking well M63 in a certain oilfield as an example, the effective reservoir thickness and permeability of well M63 are 32.9 ft and 3619 mD, respectively; the effective reservoir thickness and permeability of its adjacent well M48 are 36.9 ft and 2923 mD, respectively. In October 2020, the target well (well M63) was considered for conversion from the LU layer to the M1 layer for production. Well M48 was already in production in the M63 well area. Well M48 started production in August 2014, with an initial daily fluid production of 1609 barrels / day and a daily oil production of 383 barrels / day; by November 2020, the daily fluid production had increased to 1723 barrels / day and the daily oil production to 85 barrels / day, with a water cut of 95%.

[0125] Reference Figure 5 The image shows an example of a production dynamic curve for the target area constructed before using the static parameters proposed by the inventors of this application to correct the initial production of the target area. Without using this invention for prediction, i.e., without using the dynamic and static parameters of well M63 for correction, the predicted result for well M63 is: initial daily oil production of well M63 733 bbl / d, cumulative oil production of 500 Mbbl.

[0126] Reference Figure 6 The image shows an example of a production dynamic curve constructed after correcting the initial production rate using the static parameters of the target well, as provided in an embodiment of the present invention. The present invention also predicts the initial oil production capacity of the M1 reservoir in well M63. The predicted result is an initial daily oil production of 37 bbl / d and a cumulative oil production of 3.1 Mbbl. A comparison of the two cases shows a significant difference in the predicted results.

[0127] To verify the applicability of the present invention and the needs of actual production, the prediction results of the two scenarios were compared with the actual production dynamics.

[0128] Reference Figure 7 As shown in the relative position diagram of wells M64 and M48, well M63 underwent a layer replacement in November 2020. After the layer replacement, the actual initial daily oil production was 42 bbl / d, and the cumulative oil production reached 2.3 Mbbl by February 2021. With the application of this invention, the absolute errors of the initial daily oil production and the final cumulative oil production are only 5 bbl / d and 0.8 Mbbl, respectively. The errors are relatively small, the prediction results are more reasonable, and they are more consistent with the actual situation.

[0129] Reference Figure 8 The diagram shown is a production dynamics illustration of well M48. Figure 9 This is a schematic diagram of the production dynamics of well M63. BLPD is the daily liquid production curve, BOPD is the daily oil production curve, BSW% is the water cut, and OILCUM:403.6MB is the cumulative oil production.

[0130] Therefore, the method provided by this invention enables a relatively accurate prediction of the transition of well M63 to reservoir M1, further demonstrating the practicality of this invention.

[0131] Based on the same inventive concept, this embodiment of the invention also provides a device for predicting the production dynamics of a target well reservoir, referring to... Figure 10 As shown, the device may include: an average production rate determination module 11, a correction module 12, a reservoir comprehensive water cut determination module 13, a decrease parameter determination module 14, and a construction module 15. Its working principle is as follows:

[0132] The average production rate determination module 11 is used to determine the average production rate of the target area based on the initial production rate of at least one single well included in the target area; the average production rate determination module 11 determines the average production rate of the target area by weighted averaging based on the weight of the single well and the initial production rate of the single well.

[0133] The correction module 12 is used to correct the average production rate of the target area based on the static parameters of the target well, thereby obtaining the initial production rate of the target well. The static parameters include at least one of the following: effective thickness, permeability, porosity, and fluid viscosity. Specifically, the correction module 12 first determines the average value of at least one static parameter in the target area based on at least one static parameter from at least one of the single wells; then, it determines a correction coefficient for the static parameter based on the static parameter of the target well and the average value of the static parameter; finally, it corrects the average production rate of the target area using the correction coefficient of at least one static parameter.

[0134] The reservoir comprehensive water cut determination module 13 is used to determine the comprehensive water cut of the target area based on the water production and fluid production of all single wells in the target area.

[0135] The decline parameter determination module 14 is used to determine the decline parameters of the target area based on the daily oil production and production months of the single well. Specifically, the decline parameter determination module 14 first determines the average daily oil production of a single well based on the daily oil production and production months of at least one single well included in the target area; then, based on the fitting relationship between the average daily oil production of a single well and the production months, it determines the decline parameters of the target area; wherein, the decline parameters include: decline rate, decline index, and decline type.

[0136] The construction module 15 is used to construct the reservoir production dynamic curve of the target well based on the initial production of the target well, the comprehensive water cut of the reservoir in the target area, and the decreasing parameters of the target area.

[0137] In an optional embodiment, the device may further include: a weight determination module 16 and a filtering module 17;

[0138] The weight determination module 16 is used to determine the weight of at least one single well's impact on the production dynamics of the target area. Specifically, the weight determination module 16 determines the total production time of the single well when the target well begins production, based on the expected production time of the target well and the production time of the single well; the weight determination module 16 then applies an inverse time weighting to the total production time of the single well to determine the weight of the single well.

[0139] The screening module 17 is used to screen the individual wells included in the target area and remove individual wells that meet at least one of the following conditions: individual wells that are in a state of shutdown, individual wells in a state of abnormal production, or individual wells whose weight is less than a preset weight threshold.

[0140] Based on the same inventive concept, this embodiment of the invention also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-mentioned method for predicting the production dynamics of the target well reservoir.

[0141] Based on the same inventive concept, this embodiment of the invention also provides a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the program, it implements the above-mentioned method for predicting the production dynamics of the target well reservoir.

[0142] It should be noted that since the principles by which these devices, computer-readable storage media, and computer equipment solve the problem are similar to the aforementioned method for predicting the production dynamics of target well reservoirs, the implementation of these devices, computer-readable storage media, and computer equipment can refer to the implementation of the aforementioned method. Therefore, the specific way in which each module performs its operation in the target well reservoir production dynamics prediction device in the above embodiments has been described in detail in the embodiments of the relevant method, and will not be elaborated here.

[0143] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, systems, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage and optical storage) containing computer-usable program code.

[0144] This invention is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0145] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0146] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0147] Obviously, those skilled in the art can make various modifications and variations to this invention without departing from its spirit and scope. Therefore, if these modifications and variations fall within the scope of the claims of this invention and their equivalents, this invention also intends to include these modifications and variations.

Claims

1. A method of predicting the production performance of a target well in a reservoir, characterized in that, include: The average production rate of the target area is determined based on the initial production rate of at least one single well within the target area. Based on at least one static parameter of at least one of the single wells, determine the average value of the static parameter within the target area; based on the static parameter of the target well and the average value of the static parameter, determine the correction factor of the static parameter; The average production rate of the target area is corrected by a correction factor of at least one static parameter to obtain the initial production rate of the target well. Based on the water production and fluid production of all single wells in the target area, the overall water cut of the reservoir in the target area is determined; Based on the daily oil production and number of months of production of the single well, the decline parameters of the target area are determined; The reservoir production dynamic curve of the target well is constructed using the initial production rate of the target well, the comprehensive water cut of the target area, and the decreasing parameters of the target area.

2. The method of claim 1, wherein, Before determining the average liquid production rate of the target area, the method further includes: Determine the weight of the impact of at least one of the aforementioned single wells on the production dynamics of the target area.

3. The method of claim 2, wherein, The determination of the weight of the impact of at least one of the single wells on the production dynamics of the target area includes: Based on the expected production time of the target well and the production time of the single well, determine the total production time of the single well when the target well begins production; The weight of a single well is determined by inversely weighting the total production time of the single well.

4. The method of claim 3, wherein, Determining the average liquid production rate of the target area includes: The average production of the target area is determined by weighted averaging based on the weight of each well and its initial production.

5. The method of claim 2, wherein, Before determining the weight of the impact of at least one of the single wells on the production dynamics of the target area, the method further includes: The individual wells included in the target area are screened, and those that meet at least one of the following conditions are removed: wells that are in a state of shutdown, wells in a state of abnormal production, and wells with a weight less than a preset weight threshold.

6. The method according to any one of claims 1 to 5, characterized in that, The static parameters include at least one of the following: effective thickness, permeability, porosity, and fluid viscosity.

7. The method of claim 6, wherein, The step of determining the decline parameters of the target area based on the daily oil production and number of production months of the single well includes: The average daily oil production per well is determined based on the daily oil production of at least one well within the target area and the number of months of production. Based on the fitting relationship between the average daily oil production per well and the number of production months, the decreasing parameters of the target area are determined; The decreasing parameters include: decreasing rate, decreasing index, and decreasing type.

8. A device for predicting the production dynamics of a target well reservoir, characterized in that, include: An average production rate determination module is used to determine the average production rate of the target area based on the initial production rate of at least one single well within the target area. The correction module is used to determine the average value of the static parameter in the target area based on at least one static parameter of at least one of the single wells; and to determine the correction coefficient of the static parameter based on the static parameter of the target well and the average value of the static parameter. The average production rate of the target area is corrected by a correction factor of at least one static parameter to obtain the initial production rate of the target well. The reservoir comprehensive water cut determination module is used to determine the comprehensive water cut of the target area based on the water production and fluid production of all single wells in the target area; The decreasing parameter determination module is used to determine the decreasing parameters of the target area based on the daily oil production and number of production months of the single well; The module is used to construct the reservoir production dynamic curve of the target well based on the initial production of the target well, the comprehensive water cut of the reservoir in the target area, and the decreasing parameters of the target area.

9. The apparatus of claim 8, wherein, Also includes: Weight determination module and filtering module; The weight determination module is used to determine the weight of the impact of at least one of the single wells on the production dynamics of the target area; The filtering module is used to filter the individual wells included in the target area and remove individual wells that meet at least one of the following conditions: individual wells that are in a state of shutdown, individual wells in a state of abnormal production, or individual wells whose weight is less than a preset weight threshold.

10. A computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the method for predicting the production dynamics of a target well reservoir as described in any one of claims 1 to 7.

11. A computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the program to implement the method for predicting the production dynamics of a target well reservoir as described in any one of claims 1 to 7.

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