Gas well productivity prediction method, device, equipment and medium

Abstract

The embodiment of the invention provides a gas well productivity prediction method and device, equipment and a medium, and relates to the field of natural gas exploitation, and the method comprises the steps that the single-layer yield, the layered formation pressure and the effective reservoir thickness of an adjacent well are obtained; according to the single-layer yield of the adjacent well, the layered formation pressure and the effective reservoir thickness, a productivity contribution index is determined; according to the product of the layered formation pressure, the effective reservoir thickness and the productivity contribution index of the multiple layer sections, the open-flow capacity of the multiple layer sections is determined, and an open-flow capacity prediction model is established based on the sum of the open-flow capacity of the multiple layer sections; the stratified formation pressure and the effective reservoir thickness of the multiple layer sections of the newly-finished drilling well are input into the open flow capacity prediction model, and the open flow capacity of the newly-finished drilling well is determined; and then reasonable production allocation of the newly-finished well is determined. By means of the method, the gas well productivity can be predicted before the gas well reservoir transformation, and the problem that the cost is increased due to the fact that the gas well is subjected to reservoir transformation first and then productivity evaluation is carried out is solved.

Description

Technical Field

[0001] The present application relates to the field of natural gas extraction, and specifically, to a method, device, equipment and medium for predicting gas well production capacity. Background Art

[0002] Tight sandstone gas refers to the gas with a matrix permeability less than or equal to 0.1×10 -3 μm 2 When exploiting a gas reservoir, the first thing to do is to predict the gas well production of the gas reservoir, especially for multi-layer and multi-pressure system tight gas reservoirs. The production rules of gas wells in multi-layer and multi-pressure system tight gas reservoirs are complex, and the gas well productivity evaluation is still in the exploratory stage.

[0003] In the prior art, the method for evaluating the productivity of gas wells in tight sandstone gas reservoirs requires that the gas wells be reconstructed before the productivity of the gas wells can be evaluated. If the productivity of the gas wells is too low after the evaluation and cannot reach the predetermined productivity target, the cost of gas well development will increase due to the early gas well reservoir transformation. Summary of the invention

[0004] The present application provides a method, device, equipment and medium for predicting gas well productivity, aiming to solve the problem in related technologies that gas wells are first transformed into reservoirs and then evaluated, which leads to increased gas well development costs.

[0005] A first aspect of an embodiment of the present application provides a method for predicting gas well productivity, the method comprising:

[0006] Obtain the single-layer production of adjacent wells based on single-layer gas testing data, obtain the stratified formation pressure based on single-layer test data, and obtain the effective reservoir thickness based on well logging interpretation data;

[0007] Determine the production capacity contribution index according to the single-layer production of the adjacent wells, the layered formation pressure and the effective reservoir thickness;

[0008] Determine the open flow rates of multiple layers according to the product of the layered formation pressures of the multiple layers, the effective reservoir thickness and the productivity contribution index, and establish an open flow prediction model based on the sum of the open flow rates of the multiple layers;

[0009] Inputting the layered formation pressure and the effective reservoir thickness of multiple layers of a newly completed well into the open flow prediction model to determine the open flow of the newly completed well;

[0010] A reasonable production allocation of the newly completed well is determined according to the unimpeded flow of the newly completed well.

[0011] Optionally, determining the production capacity contribution index according to the single-layer production of the adjacent wells, the layered formation pressure and the effective reservoir thickness includes:

[0012] determining the product of the stratified formation pressure and the effective reservoir thickness;

[0013] The production capacity contribution index is obtained by dividing the single-layer production of the adjacent well by the product.

[0014] Optionally, before inputting the layered formation pressure, the effective reservoir thickness and the productivity contribution index of the newly drilled multiple layers into the open flow prediction model, the method further includes:

[0015] Determining the effective reservoir thickness of the multiple layers of the newly drilled well according to the well logging interpretation model;

[0016] The layered formation pressures of the multiple layers of the newly drilled well are determined based on the pressure data of adjacent wells.

[0017] Optionally, determining a reasonable production allocation of the newly completed well according to the unimpeded flow of the newly completed well includes:

[0018] When the open flow rate of the newly completed well is greater than or equal to the first threshold, production is allocated according to 1 / 5 to 1 / 4 of the open flow rate;

[0019] When the open flow rate of the newly completed well is greater than or equal to the second threshold value and less than the first threshold value, production is allocated according to 1 / 4 to 1 / 3 of the open flow rate;

[0020] When the open flow rate of the newly completed well is less than the second threshold, production is allocated according to 1 / 3 to 1 / 2 of the open flow rate.

[0021] Optionally, after determining a reasonable production allocation of the newly completed well according to the unimpeded flow of the newly completed well, the method further comprises:

[0022] Determine an average daily production of a single well based on the production allocation of a plurality of the newly completed wells;

[0023] Based on the average daily production of a single well and the annual target task, determine the number of gas wells required to complete the annual target task.

[0024] Optionally, after determining the open flow rate of the newly completed well, the method further comprises:

[0025] Conducting gas testing to obtain production at the later stage of the newly completed wellbore to obtain the unobstructed flow rate of the gas testing;

[0026] Determining an error rate based on the open-flow rate of the newly completed well and the open-flow rate of the test gas flow;

[0027] The reliability of the prediction result is determined based on the error rate.

[0028] Optionally, after determining a reasonable production allocation of the newly completed well according to the unimpeded flow of the newly completed well, the method further comprises:

[0029] Based on the production allocation and capacity parameter values ​​of the newly completed well, a reservoir transformation parameter value of the newly completed well is determined.

[0030] A second aspect of an embodiment of the present application provides a gas well productivity prediction device, the device comprising:

[0031] Parameter acquisition module, used to obtain the single-layer production of adjacent wells based on single-layer gas test data, obtain the layered formation pressure based on single-layer test data, and obtain the effective reservoir thickness based on well logging interpretation data;

[0032] A production capacity contribution index determination module, used to determine the production capacity contribution index according to the single-layer production of the adjacent well, the layered formation pressure and the effective reservoir thickness;

[0033] An open flow model establishment module is used to determine the open flow of multiple layers according to the layered formation pressure of multiple layers, the product of the effective reservoir thickness and the productivity contribution index, and establish an open flow prediction model based on the sum of the open flow of the multiple layers;

[0034] A newly completed well open flow prediction module, used for inputting the layered formation pressure and the effective reservoir thickness of multiple layers of the newly completed well into the open flow prediction model to determine the open flow of the newly completed well;

[0035] The newly completed well production allocation prediction module is used to determine the production allocation of the newly completed well according to the unimpeded flow of the newly completed well.

[0036] A third aspect of an embodiment of the present application provides an electronic device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, the steps of the gas well productivity prediction method described in the first aspect of the present application are implemented.

[0037] A fourth aspect of an embodiment of the present application provides a readable storage medium having a computer program / instruction stored thereon. When the computer program / instruction is executed by a processor, the steps in the gas well productivity prediction method described in the first aspect of the present application are implemented.

[0038] Beneficial effects:

[0039] The present application provides a method for predicting gas well productivity, the method comprising: obtaining the single-layer production of adjacent wells according to single-layer gas test data, obtaining the stratified formation pressure according to single-layer test data, and obtaining the effective reservoir thickness according to logging interpretation data; determining the productivity contribution index according to the single-layer production of the adjacent wells, the stratified formation pressure and the effective reservoir thickness; determining the unimpeded flow of multiple layers according to the product of the stratified formation pressure, the effective reservoir thickness and the productivity contribution index of multiple layers, and establishing an unimpeded flow prediction model based on the sum of the unimpeded flow of the multiple layers; inputting the stratified formation pressure, the effective reservoir thickness and the productivity contribution index of multiple layers of the newly completed well into the unimpeded flow prediction model to determine the unimpeded flow of the newly completed well; and determining the reasonable production allocation of the newly completed well according to the unimpeded flow of the newly completed well. Through this method, the prediction of the productivity of the gas well can be completed before the gas well reservoir is transformed, solving the problem of increased costs caused by the productivity assessment after the gas well reservoir is transformed. This method can be used to evaluate whether a completed well has the potential for reservoir transformation, and to formulate reasonable differentiated transformation plans based on the evaluation results to achieve the goal of efficient development. If the production capacity is too low, there is no need to carry out reservoir transformation to avoid investment waste. BRIEF DESCRIPTION OF THE DRAWINGS

[0040] In order to more clearly illustrate the technical solutions of the embodiments of the present application, the drawings required for use in the description of the embodiments of the present application will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying any creative labor.

[0041] Figure 1 This is a flow chart of a gas well productivity prediction method provided by an embodiment of the present application;

[0042] Figure 2 This is an example productivity contribution index statistical chart of a gas well productivity prediction method provided in an embodiment of the present application;

[0043] Figure 3 This is a schematic diagram of a gas well productivity prediction device provided in one embodiment of the present application. DETAILED DESCRIPTION

[0044] The following will be combined with the drawings in the embodiments of the present application to clearly and completely describe the technical solutions in the embodiments of the present application. Obviously, the described embodiments are part of the embodiments of the present application, not all of the embodiments. Based on the embodiments in the present application, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of this application.

[0045] The productivity evaluation of gas wells in tight gas reservoirs includes reasonable production allocation, decline rate, and final cumulative gas production. In the early stage of gas reservoir development, the productivity evaluation of gas wells mainly focuses on the analysis of average daily gas production, which generally includes the daily gas production during the stable production period of the first three years before production and the average daily gas production in the first year. Since tight gas wells basically do not have a stable production period and begin to decline after production, the prediction and evaluation of the average daily gas production in the first year is more critical.

[0046] In related technologies, the prediction and evaluation of the average daily gas production of a gas well in the first year is usually to perform fracturing on the effective reservoir according to the logging interpretation conclusion after the tight sandstone gas well is drilled and completed, and then conduct gas testing to determine production. However, such methods require reservoir transformation, dynamic testing or formal production, which are high in investment, time-consuming and complex in process, and are difficult to meet the needs of rapid and effective evaluation of gas well benefits and reasonable decision-making and deployment in the early stage of gas field development.

[0047] In view of this, an embodiment of the present application proposes a method for predicting gas well productivity.

[0048] like Figure 1 As shown, Figure 1 A flow chart of a gas well productivity prediction method provided in this embodiment. The method comprises the following steps:

[0049] S11: Obtain the single-layer production of adjacent wells based on single-layer gas testing data, obtain the stratified formation pressure based on single-layer test data, and obtain the effective reservoir thickness based on well logging interpretation data.

[0050] In this embodiment, formation pressure refers to the pressure acting on the fluid (oil, gas and water) in the rock pores, and stratified formation pressure refers to the formation pressure of one layer of the gas well. Neighboring wells refer to wells around the well to be developed that have completed gas testing. There is more than one well around that has completed gas testing, so neighboring wells do not represent only one well, but all surrounding wells with similar characteristics to the well to be developed. The single-layer production of neighboring wells refers to the gas production of a certain layer of the neighboring well. The effective reservoir thickness refers to the thickness of a certain layer in the gas layer that has gas production capacity.

[0051] In this embodiment, the single-layer gas test data is the data obtained after the gas test of multiple wells is completed, and the single-layer test data is also the data that can be obtained after the drilling of multiple wells is completed. The single-layer gas test data and the single-layer test data are dynamic data, and the dynamic data include the single-layer production, layer pressure and fluid characteristics of adjacent wells in multiple effective layers. The logging interpretation data is also the data obtained after the drilling is completed, which is static data, including the effective reservoir thickness, porosity, gas saturation, etc. of multiple effective layers. Among them, the effective layer section is the layer section with effective gas production capacity in the gas well, and the "layer section" hereinafter is all represented as "effective layer section".

[0052] In addition, in this application, the stratified formation pressure of a certain layer obtained from the data and the production of adjacent wells of a certain layer obtained from the data are the same number of layers, and the same applies to the effective reservoir thickness. For example, if the stratified formation pressure of layer a of multiple wells is obtained from the data, then the single-layer production and effective reservoir thickness of the adjacent wells that match it should be obtained from layer a of multiple wells in the data, rather than layer b or other layers.

[0053] S12: Determine a production capacity contribution index according to the single-layer production of the adjacent wells, the stratified formation pressure and the effective reservoir thickness.

[0054] In this embodiment, the productivity contribution index is determined by the stratified formation pressure, the single-layer production of adjacent wells and the effective reservoir thickness. Since the sedimentary microfacies types, fluid characteristics, pressure coefficients, etc. of different layers in the gas well are not completely the same, the single-layer production of adjacent wells, stratified formation pressure and effective reservoir thickness of different layers in the gas well are different, and the productivity contribution index determined by these three factors has different values ​​in different layers.

[0055] S13: determining the open flow rates of multiple layers according to the layered formation pressures of the multiple layers, the product of the effective reservoir thickness and the productivity contribution index, and establishing an open flow prediction model based on the sum of the open flow rates of the multiple layers.

[0056] In this embodiment, the unimpeded flow rate represents the daily production of the gas well when the bottom hole pressure is equal to one atmosphere (i.e., when the bottom hole is completely open). Since the tight sandstone gas reservoir has multiple effective layers developed vertically, a multi-layer combined production method is adopted for exploitation. Multi-layer combined production refers to a well that simultaneously perforates multiple gas layers for production. In order to facilitate the calculation of the unimpeded flow rate of the gas well, this embodiment proposes to construct an unimpeded flow rate prediction model for the gas well, that is, the product of the production capacity contribution index of a certain layer segment and the effective reservoir thickness and the stratified formation pressure is the unimpeded flow rate of the layer segment, and the sum of the unimpeded flow rates of each layer segment is the unimpeded flow rate prediction model for single-well multi-layer combined production.

[0057] Specifically, the formula of the unimpeded flow prediction model is as follows:

[0058] Q AOF =a1×P1×H1+a2×P2×H2+a3×P3×H3+……+a n ×P n ×H n

[0059] Where n is a positive integer, Q AOF is the unobstructed flow rate of the gas well, a1, a2, a3, a n It is the production capacity contribution index of each layer segment, P1, P2, P3, P n is the layered formation pressure of each layer, H1, H2, H3, H nis the effective reservoir thickness of each layer, a n ×P n ×H n is the unimpeded flow rate of the nth layer segment.

[0060] S14: Inputting the layered formation pressure and the effective reservoir thickness of multiple layers of the newly completed well into the open flow prediction model to determine the open flow of the newly completed well.

[0061] In this embodiment, a newly completed well refers to a well that has reached a predetermined depth and the expected purpose of the construction and has been completed. According to the constructed open flow prediction model, the effective reservoir thickness and layered formation pressure of each layer section of the newly completed well are input into the open flow prediction model. Here, the model already has the capacity contribution index of each layer section, which is determined by step S12. The open flow value of the newly completed well, that is, the daily production of the well, is obtained by calculation.

[0062] S15: Determine a reasonable production allocation for the newly completed well according to the unimpeded flow rate of the newly completed well.

[0063] In this embodiment, because the actual daily production of the gas well during gas well exploitation is affected by factors such as the gas well environment and the equipment used during construction and exploitation, the actual daily production after gas well exploitation is different from the daily production in the open flow prediction model. Production allocation is to predict the actual daily production based on the open flow predicted by the open flow prediction model.

[0064] In another embodiment of the present application, step S12 specifically includes:

[0065] S21: Determine the product of the layered formation pressure and the effective reservoir thickness; divide the single-layer production of the adjacent well by the product to obtain the production capacity contribution index.

[0066] In this embodiment, the productivity contribution index of different layers can be calculated by obtaining the single-layer production of adjacent wells from the single-layer gas test data, obtaining the layered formation pressure from the single-layer test data, and obtaining the effective reservoir thickness from the logging interpretation data. The productivity contribution index calculation formula for a specific layer segment is:

[0067] Production capacity contribution index = single layer production of adjacent wells ÷ (stratified formation pressure × effective reservoir thickness)

[0068] In another embodiment of the present application, before inputting the layered formation pressure, the effective reservoir thickness and the productivity contribution index of the newly drilled multiple layers into the open flow prediction model, the method further includes:

[0069] S31: Determine the effective reservoir thickness of the multiple layer sections of the newly drilled well according to the well logging interpretation model.

[0070] S32: Determine the layered formation pressures of the multiple layers of the newly drilled well based on the pressure data of the adjacent wells.

[0071] In this embodiment, the well logging interpretation model refers to the mapping relationship from the well logging plate generated by the well logging data to the effective reservoir with obvious geological meaning. When the unobstructed flow of the newly completed well is to be predicted, the stratified formation pressure of each layer of the newly completed well is determined based on the pressure data of the adjacent wells that have been recorded; based on the continuously optimized well logging interpretation model and reliable interpretation conclusions, the effective reservoir thickness of each layer of the newly completed well is determined. When determining the stratified formation pressure of a layer of the newly completed well, the pressure data of the well is not obtained after the newly completed well is opened, and it is necessary to obtain pressure data from the same layer of the adjacent well. For example: to determine the stratified formation pressure of layer a of well A, the relevant pressure values ​​are obtained based on the existing pressure data of layer a of well B close to well A. After the newly completed well is opened, the effective reservoir thickness of the well itself can be obtained through the well logging interpretation model.

[0072] In another embodiment of the present application, step S15 specifically includes:

[0073] S41: When the open-flow rate of the newly completed well is greater than or equal to a first threshold value, production is allocated according to 1 / 5 to 1 / 4 of the open-flow rate; when the open-flow rate of the newly completed well is greater than or equal to a second threshold value and less than the first threshold value, production is allocated according to 1 / 4 to 1 / 3 of the open-flow rate; when the open-flow rate of the newly completed well is less than the second threshold value, production is allocated according to 1 / 3 to 1 / 2 of the open-flow rate.

[0074] In this embodiment, due to the influence of the environment around the gas well and the equipment used during production, the actual daily gas production of the newly completed well after production is less than the unobstructed flow rate predicted by the unobstructed flow model. Depending on the different locations of the gas reservoirs and the different values ​​of the predicted unobstructed flow rate, the proportion of production allocation for the predicted unobstructed flow rate is also different.

[0075] For example, in the Ordos Basin, the predicted open-flow rate of its tight gas reservoir is used to predict the reasonable production capacity of newly completed wells. When the open-flow rate is greater than or equal to 40,000 cubic meters / day, the production is allocated at 1 / 5 to 1 / 4 of the open-flow rate; when the open-flow rate is greater than or equal to 20,000 cubic meters / day and less than 40,000 cubic meters / day, the production is allocated at 1 / 4 to 1 / 3 of the open-flow rate; when the open-flow rate is less than 20,000 cubic meters / day, the production is allocated at 1 / 3 to 1 / 2 of the open-flow rate.

[0076] In another embodiment of the present application, after determining the reasonable production allocation of the newly completed well according to the unimpeded flow of the newly completed well, the method further includes:

[0077] S51: Based on the production allocation of the multiple newly completed wells, determine the average daily production of a single well; based on the average daily production of a single well and the annual target task, determine the number of gas wells required to complete the annual target task.

[0078] In this embodiment, after the actual daily production of multiple newly completed wells is predicted, the average daily production of a single well is obtained by dividing the total daily production of multiple newly completed wells by the number of newly completed wells; and then the number of gas wells required to complete this task target is determined based on the annual task target for the tight gas reservoir where the well is located. The annual task target refers to the daily gas production that the gas reservoir needs to achieve within the first year.

[0079] For example, 172 development wells have been drilled in a tight sandstone block in the Ordos Basin. Using the above-mentioned gas well capacity prediction method, it is predicted that the average daily production of the gas wells in the first year will be 10,000 cubic meters per day. If all the drilled wells in the gas reservoir are put into production, the gas reservoir can form a production capacity of 1.72 million cubic meters per day. According to the annual task target, the overall gas production of the gas reservoir needs to reach 3 million cubic meters per day by the end of the year, so 128 new wells need to be drilled.

[0080] In another embodiment of the present application, the gas well productivity prediction method further includes:

[0081] S61: Conducting a gas test to calculate production at a later stage of the newly completed wellbore to obtain an unobstructed flow rate of the gas test; determining an error rate based on the unobstructed flow rate of the newly completed wellbore and the unobstructed flow rate of the gas test; and determining the reliability of the prediction result based on the error rate.

[0082] In this embodiment, after the late stage of reservoir transformation of the newly completed well, i.e., gas testing for production, the unimpeded flow rate of the test gas of the well is determined. According to the unimpeded flow rate of the newly completed well determined by the unimpeded flow rate model and the test gas unimpeded flow rate of the newly completed well, the difference between the unimpeded flow rate and the test gas unimpeded flow rate is divided by the test gas unimpeded flow rate to obtain the error rate. The value of the error rate is less than a certain threshold, i.e., the unimpeded flow rate determined by the unimpeded flow rate model before the reservoir transformation is approximately the test gas unimpeded flow rate after the reservoir transformation, which proves the accuracy of the unimpeded flow rate value determined by the unimpeded flow rate model. The threshold value varies with the different gas reservoir environments.

[0083] In another embodiment of the present application, after determining the reasonable production allocation of the newly completed well according to the unimpeded flow of the newly completed well, the gas well productivity prediction method further includes:

[0084] S71: Determine a reservoir transformation parameter value of the newly completed well based on the production allocation and capacity parameter values ​​of the newly completed well.

[0085] In this embodiment, the capacity parameter value refers to the economic benefit represented by the predicted daily production of the newly completed well. Based on the prediction of the actual daily production of the newly completed well and the economic benefit of the capacity, it is judged whether the newly completed well has the value of reservoir transformation, and the economic benefit of the newly completed well after the reservoir transformation is determined.

[0086] In order to better illustrate the present application, the present application provides the following specific examples:

[0087] Taking a tight sandstone block in the eastern part of the Ordos Basin as an example, the single-layer gas testing data, single-layer test data and single-layer logging interpretation data of 38 wells in the block that have been completed were statistically analyzed, and the strata involved were the Shanxi Formation, Taiyuan Formation and Benxi Formation.

[0088] The study determined that the target layer for block development is generally deltaic sediments, distributary channels are favorable microfacies, the pressure coefficients of each layer are quite different, the Benxi Formation is a normal pressure gas reservoir, and other layers are low pressure gas reservoirs. The single-layer production of adjacent wells is determined by single-layer gas test data, the stratified formation pressure is determined by single-layer test data, and the effective reservoir thickness is determined by single-layer logging interpretation data. The production capacity contribution indexes of the Shanxi Formation, Taiyuan Formation, and Benxi Formation are calculated to be 0.0203 million cubic meters / MPa.dm, 0.0214 million cubic meters / MPa.dm, and 0.0844 million cubic meters / MPa.dm, respectively. Figure 2 As shown, Figure 2 This is an example productivity contribution index statistical chart of a gas well productivity prediction method.

[0089] Constructing a gas well open flow prediction model:

[0090] QAOF=0.0203×P 山西 ×H 山西 +0.0214×P 太原 ×H 太原 +0.0844×P 本溪 ×H 本溪

[0091] Well logging interpretation of the newly completed well J33-2C1 shows that the effective reservoir thickness of the Shanxi, Taiyuan and Benxi formations are 3.3m, 3.7m and 1.4m respectively. Based on the pressure data of adjacent wells, the formation pressures of the Shanxi, Taiyuan and Benxi formations in this well are predicted to be 16.2MPa, 17.1MPa and 20.4MPa respectively. According to the constructed prediction model, the multi-layer combined production unimpeded flow rate of this well is predicted to be 48,500 cubic meters per day.

[0092] The well was later tested for gas production, and the unobstructed flow rate was 46,500 cubic meters per day, with an error rate of 4.3%. The prediction results are reliable.

[0093] Finally, the reasonable production capacity of the newly completed wells was predicted by using the unimpeded flow production allocation method of tight gas reservoirs in the Ordos Basin. The well was predicted to have an unimpeded flow of 48,500 cubic meters per day. The production was allocated at 1 / 5 to 1 / 4 of the unimpeded flow, and the reasonable production of a single well was estimated to be 9,700 to 12,000 cubic meters per day.

[0094] Through the gas well capacity prediction method provided in this application, the gas well capacity prediction can be completed before the gas well reservoir is transformed, which solves the problem of increased costs caused by the capacity evaluation of the gas well after the reservoir is transformed, and at the same time shortens the time of gas well capacity prediction and improves the prediction efficiency. This method can be used to evaluate whether the development of gas reservoirs has economic value. If the initial capacity of the gas well is higher than the economic limit production standard, the possibility of efficient development is high. It can also be used to evaluate whether the completed well has the potential for reservoir transformation, and formulate a reasonable differentiated transformation plan based on the evaluation results to achieve the purpose of efficient development. If the capacity is too low, there is no need to transform the reservoir to avoid investment waste. The production capacity of the gas reservoir at different time nodes can be predicted based on the number of completed wells, and the natural gas supply capacity of the gas reservoir can be effectively predicted, providing favorable support for the determination of the scale and progress of ground supporting engineering construction. This method can be used to scientifically guide the arrangement of drilling workload during the production construction period and the stable production period of the gas field, and strongly support the deployment of capacity construction.

[0095] Based on the same inventive concept, an embodiment of the present application provides a gas well productivity prediction device. Figure 3 , Figure 3 FIG. 3 is a schematic diagram of a gas well productivity prediction device 300 proposed in an embodiment of the present application. Figure 3 As shown, the device comprises:

[0096] Parameter acquisition module, used to obtain the single-layer production of adjacent wells based on single-layer gas test data, obtain the layered formation pressure based on single-layer test data, and obtain the effective reservoir thickness based on well logging interpretation data;

[0097] A production capacity contribution index determination module, used to determine the production capacity contribution index according to the single-layer production of the adjacent well, the layered formation pressure and the effective reservoir thickness;

[0098] An open flow model establishment module is used to determine the open flow of multiple layers according to the layered formation pressure of multiple layers, the product of the effective reservoir thickness and the productivity contribution index, and establish an open flow prediction model based on the sum of the open flow of the multiple layers;

[0099] A newly completed wellbore open flow prediction module, which inputs the layered formation pressure of multiple layers of the newly completed wellbore, the effective reservoir thickness and the productivity contribution index into the open flow prediction model to determine the open flow of the newly completed wellbore;

[0100] The newly completed well production allocation prediction module determines the production allocation of the newly completed well according to the unimpeded flow of the newly completed well.

[0101] Based on the same inventive concept, another embodiment of the present application provides an electronic device, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein when the processor executes, the steps in the gas well productivity prediction method described in any of the above embodiments of the present application are implemented.

[0102] Based on the same inventive concept, another embodiment of the present application provides a readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the steps in the gas well productivity prediction method as described in any of the above embodiments of the present application.

[0103] The various embodiments in this specification are described in a progressive manner, and each embodiment focuses on the differences from other embodiments. The same or similar parts between the various embodiments can be referenced to each other.

[0104] Those skilled in the art will appreciate that the embodiments of the present application may be provided as methods, devices, or computer program products. Therefore, the embodiments of the present application may adopt the form of a complete hardware embodiment, a complete software embodiment, or an embodiment in combination with software and hardware. Moreover, the embodiments of the present application may adopt the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program codes.

[0105] Although the preferred embodiments of the present application have been described, those skilled in the art may make additional changes and modifications to these embodiments once they have learned the basic creative concept. Therefore, the appended claims are intended to be interpreted as including the preferred embodiments and all changes and modifications that fall within the scope of the embodiments of the present application.

[0106] In the description of this specification, the description with reference to the terms "one embodiment", "some embodiments", "illustrative embodiments", "examples", "specific examples", or "some examples" means that the specific features, structures, materials or characteristics described in conjunction with the embodiment or example are included in at least one embodiment or example of the present invention. In this specification, the schematic representation of the above terms does not necessarily refer to the same embodiment or example. Moreover, the specific features, structures, materials or characteristics described may be combined in any one or more embodiments or examples in a suitable manner.

[0107] Moreover, the terms "include", "comprises" or any other variation thereof are intended to cover non-exclusive inclusion, so that a process, method, article or terminal device that includes a series of elements includes not only those elements, but also includes other elements not explicitly listed, or also includes elements inherent to such process, method, article or terminal device. In the absence of further restrictions, the elements defined by the sentence "comprises a ..." do not exclude the existence of other identical elements in the process, method, article or terminal device that includes the elements. The character " / " generally indicates that the objects associated with each other are in an "or" relationship.

[0108] The above is a detailed introduction to a gas well productivity prediction method, device, equipment and medium provided by the present application. Specific examples are used in this article to illustrate the principles and implementation methods of the present application. The description of the above embodiments is only used to help understand the method of the present application and its core idea; at the same time, for general technical personnel in this field, according to the idea of ​​the present application, there will be changes in the specific implementation method and application scope. In summary, the content of this specification should not be understood as a limitation on the present application.

Claims

1. A method for predicting gas well productivity, characterized in that: The method comprises: Obtain the single-layer production of adjacent wells based on single-layer gas testing data, obtain the stratified formation pressure based on single-layer test data, and obtain the effective reservoir thickness based on well logging interpretation data; Determine the production capacity contribution index according to the single-layer production of the adjacent wells, the layered formation pressure and the effective reservoir thickness; Determine the open flow rates of multiple layers according to the product of the layered formation pressures of the multiple layers, the effective reservoir thickness and the productivity contribution index, and establish an open flow prediction model based on the sum of the open flow rates of the multiple layers; Inputting the layered formation pressure and the effective reservoir thickness of multiple layers of a newly completed well into the open flow prediction model to determine the open flow of the newly completed well; A reasonable production allocation of the newly completed well is determined according to the unimpeded flow of the newly completed well.

2. The method for predicting gas well productivity according to claim 1, characterized in that: Determining the production capacity contribution index according to the single-layer production of the adjacent wells, the layered formation pressure and the effective reservoir thickness includes: determining the product of the stratified formation pressure and the effective reservoir thickness; The production capacity contribution index is obtained by dividing the single-layer production of the adjacent well by the product.

3. The method for predicting gas well productivity according to claim 1, characterized in that: Before inputting the layered formation pressure, the effective reservoir thickness and the productivity contribution index of the newly drilled multiple layers into the open flow prediction model, the method further includes: Determining the effective reservoir thickness of the multiple layers of the newly drilled well according to the well logging interpretation model; The layered formation pressures of the multiple layers of the newly drilled well are determined based on the pressure data of adjacent wells.

4. The method for predicting gas well productivity according to claim 1, characterized in that: According to the unimpeded flow of the newly completed well, determine the reasonable production allocation of the newly completed well, including: When the open flow rate of the newly completed well is greater than or equal to the first threshold, production is allocated according to 1 / 5 to 1 / 4 of the open flow rate; When the open flow rate of the newly completed well is greater than or equal to the second threshold value and less than the first threshold value, production is allocated according to 1 / 4 to 1 / 3 of the open flow rate; When the open flow rate of the newly completed well is less than the second threshold, production is allocated according to 1 / 3 to 1 / 2 of the open flow rate.

5. The method for predicting gas well productivity according to claim 1, characterized in that: After determining the reasonable production allocation of the newly completed well according to the unimpeded flow of the newly completed well, the method further includes: Determine an average daily production of a single well based on the production allocation of a plurality of the newly completed wells; Based on the average daily production of a single well and the annual target task, determine the number of gas wells required to complete the annual target task.

6. The method for predicting gas well productivity according to claim 1, characterized in that: After determining the open flow rate of the newly completed well, the method further includes: Conducting gas testing to obtain production at the later stage of the newly completed wellbore to obtain the unobstructed flow rate of the gas testing; Determining an error rate based on the open-flow rate of the newly completed well and the open-flow rate of the test gas flow; The reliability of the prediction result is determined based on the error rate.

7. The method for predicting gas well productivity according to claim 4, characterized in that: After determining the reasonable production allocation of the newly completed well according to the unimpeded flow of the newly completed well, the method further includes: Based on the production allocation and capacity parameter values ​​of the newly completed well, a reservoir transformation parameter value of the newly completed well is determined.

8. A gas well productivity prediction device, characterized in that: The device comprises: Parameter acquisition module, used to obtain the single-layer production of adjacent wells based on single-layer gas test data, obtain the layered formation pressure based on single-layer test data, and obtain the effective reservoir thickness based on well logging interpretation data; A production capacity contribution index determination module, which determines the production capacity contribution index according to the single-layer production of the adjacent well, the layered formation pressure and the effective reservoir thickness; An open flow model establishment module is used to determine the open flow of multiple layers according to the layered formation pressure of multiple layers, the product of the effective reservoir thickness and the productivity contribution index, and establish an open flow prediction model based on the sum of the open flow of the multiple layers; A newly completed well open flow prediction module, used for inputting the layered formation pressure and the effective reservoir thickness of multiple layers of the newly completed well into the open flow prediction model to determine the open flow of the newly completed well; The production allocation prediction module for a newly completed well is used to determine the reasonable production allocation of the newly completed well according to the unimpeded flow of the newly completed well.

9. An electronic device comprising a memory, a processor and a computer program stored in the memory, characterized in that: The processor executes the computer program to implement the gas well productivity prediction method according to any one of claims 1 to 7.

10. A computer-readable storage medium having a computer program / instruction stored thereon, characterized in that: When the computer program / instruction is executed by a processor, the gas well productivity prediction method according to any one of claims 1 to 7 is implemented.

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