Method for evaluating recoverable resources of tight oil reservoirs and related equipment

Abstract

The present application provides a kind of compact oil reservoir recoverable resource quantity evaluation method and related equipment, wherein the method comprises: obtaining the initial stage actual production of evaluation well, and the evaluation well is the horizontal well drilled in the evaluation area;According to the initial stage actual production, the estimated cumulative production of evaluation well is determined;The actual reservoir drilling rate and the actual length of horizontal section of evaluation well are obtained;According to the estimated cumulative production, the actual reservoir drilling rate and the actual length of horizontal section, the recoverable resource quantity of evaluation area is determined.The compact oil reservoir recoverable resource quantity evaluation method provided by the present application can more accurately reflect the actual situation of evaluation area using the related data of evaluation well, improve the pertinence and authenticity of the evaluation of recoverable resource quantity of evaluation area, and greatly improve the evaluation accuracy of the recoverable resource quantity of evaluation area, provide more accurate and reliable reference for subsequent development work of evaluation area, and improve the economy and efficiency of compact oil reservoir development.

Description

Technical Field

[0001] This invention relates to the field of tight oil reservoir evaluation technology, and in particular to a method and related equipment for evaluating the recoverable resources of tight oil reservoirs. Background Technology

[0002] In the development of tight oil reservoirs, accurately assessing the recoverable resources during the exploration and evaluation phase is of great practical significance for the subsequent economic development of the reservoirs.

[0003] However, the assessment of recoverable resources in tight oil reservoirs in related technologies is usually based on exploration results and combined with empirical data from other oil reservoir blocks with higher levels of development. This often results in a lack of specificity in the estimation results, leading to poor accuracy in the assessment of recoverable resources and making it difficult to provide a reliable reference for the subsequent development of tight oil reservoirs. Summary of the Invention

[0004] The present invention aims to solve at least one of the technical problems existing in the prior art or related art.

[0005] Therefore, the first aspect of the present invention provides a method for evaluating the recoverable resources of tight oil reservoirs.

[0006] A second aspect of the present invention provides an apparatus for evaluating the recoverable resources of tight oil reservoirs.

[0007] A third aspect of the present invention provides a storage medium.

[0008] A fourth aspect of the present invention provides an electronic device.

[0009] In view of this, a method for evaluating the recoverable resources of tight oil reservoirs is proposed according to a first aspect of the embodiments of this application, comprising:

[0010] To obtain the initial stage actual production of the appraisal well, which is a drilled horizontal well located within the appraisal area;

[0011] Based on the actual production in the initial stage, determine the estimated cumulative production of the appraisal well;

[0012] Obtain the actual reservoir encounter rate and actual horizontal section length of the appraisal well;

[0013] The recoverable resources in the evaluation area are determined based on the estimated cumulative production, actual reservoir encounter rate, and actual length of the horizontal section.

[0014] In one feasible implementation, the step of determining the estimated cumulative production of the appraisal well based on the actual production in the initial stage includes:

[0015] To obtain the production rate at each stage of the calibration well, the calibration well is a tight oil horizontal well in the calibration zone;

[0016] Based on the actual production in the initial stage and the production at the stage calibration, determine the expected production of the appraisal well in that stage;

[0017] The estimated cumulative output is determined based on the actual output in the initial stage and the projected output for the stage.

[0018] In one feasible implementation, the step of determining the stage-expected production of the appraisal well based on the initial stage actual production and the stage-calibrated production includes:

[0019] Determine the stage production scale decline rate of the calibrated well based on the production output at each stage.

[0020] The stage production decline rate is determined as the expected stage production decline rate of the appraisal well.

[0021] The stage-expected production of the appraisal well is determined based on the actual production in the initial stage and the expected production decline rate in the stage.

[0022] In one feasible implementation, the number of appraisal wells is greater than or equal to one.

[0023] In one feasible implementation, the step of determining the recoverable resources of the evaluation area based on the estimated cumulative production, actual reservoir encounter rate, and actual horizontal segment length includes:

[0024] Obtain the horizontal well spacing in the evaluation area. The horizontal wells in the evaluation area include planned development wells and evaluation wells. The planned development wells are the horizontal wells to be drilled located in the evaluation area.

[0025] Obtain the estimated reservoir encounter rate in the evaluation area;

[0026] Obtain the effective oil-bearing area of ​​the evaluation zone;

[0027] The recoverable resources are determined based on the horizontal well spacing, estimated reservoir encounter rate, effective oil-bearing area, estimated cumulative production, actual reservoir encounter rate, and actual length of the horizontal section; or

[0028] Obtain the degree of well control of the horizontal wells in the evaluation area;

[0029] The recoverable resources are determined based on the horizontal well spacing, estimated reservoir encounter rate, effective oil-bearing area, estimated cumulative production, actual reservoir encounter rate, actual length of horizontal section, and well control degree of horizontal wells.

[0030] In one feasible implementation, the step of obtaining the horizontal well spacing of the evaluation area includes:

[0031] Obtain fracturing monitoring data from the appraisal well;

[0032] The horizontal well spacing is determined based on fracturing monitoring data.

[0033] In one feasible implementation, the step of obtaining the estimated reservoir drilling rate for the evaluation area includes:

[0034] The reference reservoir encounter rate of multiple reference wells is obtained. The reference wells are drilled horizontal wells located in the reference area, and the reference area and the evaluation area are located in the same region.

[0035] Determine the average drilling rate of multiple reference reservoirs;

[0036] The mean drilling rate is used to estimate the reservoir drilling rate.

[0037] In one feasible implementation, the step of obtaining the well control level of the horizontal well in the evaluation area includes:

[0038] Obtain the total number of horizontal wells in the evaluation area;

[0039] Obtain the average well control area per well in the evaluation area;

[0040] The total well-controlled area of ​​the evaluation area is determined based on the total number of horizontal wells and the average well-controlled area per well in the evaluation area.

[0041] The degree of well control of the horizontal wells in the evaluation area is determined based on the total well-controlled area and the effective oil-bearing area of ​​the evaluation area.

[0042] In one feasible implementation, the step of obtaining the average well-controlled area per well in the evaluation zone includes:

[0043] Obtain the planned length of the horizontal section of the development well;

[0044] The average length of a single well horizontal section in the evaluation area is determined based on the planned length and the actual length of the horizontal section.

[0045] The average well-controlled area per well is determined based on the average length of the horizontal section of a single well and the horizontal well spacing in the evaluation area.

[0046] According to a second aspect of the embodiments of this application, a device for evaluating the recoverable resources of tight oil reservoirs is provided, comprising:

[0047] The first acquisition module is used to acquire the initial stage actual production of the appraisal well, which is a drilled horizontal well located in the appraisal area.

[0048] The first determination module is used to determine the estimated cumulative production of the appraisal well based on the actual production in the initial stage;

[0049] The second acquisition module is used to acquire the actual reservoir drilling rate and the actual length of the horizontal section of the appraisal well.

[0050] The second determination module is used to determine the recoverable resources in the evaluation area based on the estimated cumulative production, actual reservoir drilling rate, and actual length of the horizontal section.

[0051] According to a third aspect of the embodiments of this application, a storage medium is provided, the storage medium including a stored program, wherein, when the program is running, the device where the storage medium is located is controlled to execute the method as described in any of the first aspects above.

[0052] According to a fourth aspect of the embodiments of this application, an electronic device is provided, the electronic device including at least one processor and at least one memory connected to the processor, wherein the processor is configured to invoke program instructions in the memory to execute the method as proposed in any of the first aspects above.

[0053] Compared to existing technologies, the present invention offers at least the following advantages: The method for evaluating the recoverable resources of tight oil reservoirs provided in this application obtains the actual production of the appraisal well in its initial stage. Based on this initial stage production, the estimated cumulative production of the appraisal well is determined, and combined with the actual reservoir encounter rate and the actual length of the horizontal section, the recoverable resources of the appraisal area are determined. Furthermore, since the appraisal well is a drilled horizontal well located within the appraisal area, its data more accurately reflects the actual situation of the appraisal area, improving the relevance and accuracy of the evaluation of recoverable resources. Moreover, since the appraisal well has completed its initial stage of actual production, highly accurate initial stage production, actual reservoir encounter rate, and actual length of the horizontal section can be obtained. This ensures the accuracy of the estimated cumulative production of the appraisal well and significantly improves the accuracy of the evaluation of recoverable resources in the appraisal area, providing a more accurate and reliable reference for subsequent development work in the appraisal area and enhancing the economy and efficiency of tight oil reservoir development. Attached Figure Description

[0054] Various other advantages and benefits will become apparent to those skilled in the art upon reading the following detailed description of exemplary embodiments. The accompanying drawings are for illustrative purposes only and are not intended to limit the scope of this application. Furthermore, the same reference numerals denote the same parts throughout the drawings. In the drawings:

[0055] Figure 1 A schematic flowchart illustrating an embodiment of a method for evaluating recoverable resources in tight oil reservoirs provided in this application;

[0056] Figure 2 A schematic structural block diagram of a device for evaluating recoverable resources in tight oil reservoirs according to an embodiment of this application;

[0057] Figure 3 A schematic structural block diagram of an electronic device according to an embodiment of this application. Detailed Implementation

[0058] Exemplary embodiments of the present application will now be described in more detail with reference to the accompanying drawings. While exemplary embodiments of the present application are shown in the drawings, it should be understood that the present application 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 application will be thorough and complete, and will fully convey the scope of the present application to those skilled in the art.

[0059] According to a first aspect of the embodiments of this application, a method for evaluating the recoverable resources of tight oil reservoirs is proposed, such as... Figure 1 As shown, it includes:

[0060] Step S101: Obtain the initial stage actual production of the appraisal well, which is a drilled horizontal well located within the appraisal area;

[0061] Specifically, the evaluation area is the tight oil reservoir block to be evaluated, and the evaluation well is a drilled horizontal well within the evaluation area that has completed the initial stage of actual production. The initial stage refers to the first production stage after the evaluation well is completed and fracturing and put into production. The actual production in the initial stage can be obtained based on the production statistics of the evaluation well.

[0062] It is understandable that production stages can be divided according to production time periods, such as one year as a production stage. Correspondingly, the actual output in the initial stage can be understood as the output in the first year after the appraisal well is put into production. Of course, it is also possible to divide the production stage into two or three years. Similarly, it can also be divided into one month or multiple months. No further restrictions are imposed here.

[0063] Step S102: Determine the estimated cumulative production of the appraisal well based on the actual production in the initial stage;

[0064] Specifically, based on the actual production of the appraisal well in the initial stage, the production of the appraisal well in the future production stage can be estimated, thereby obtaining the cumulative production of the appraisal well. Then, based on the estimated cumulative production of the appraisal well, the recoverable resources in the appraisal area can be analyzed and determined.

[0065] Methods for obtaining cumulative output from actual output in the initial stage include, but are not limited to, the empirical output reduction method and the scale analogy method; no further restrictions are imposed here.

[0066] Step S103: Obtain the actual reservoir encounter rate and the actual length of the horizontal section of the appraisal well;

[0067] Specifically, since appraisal wells are drilled horizontal wells, the actual reservoir encounter rate and the actual length of the horizontal section can be obtained from the appraisal well's logging information, such as the logging composite chart or logging interpretation results table. Furthermore, based on the actual reservoir encounter rate of the appraisal wells, the reservoir distribution and the degree of effective reservoir utilization in the appraisal area can be more accurately reflected, providing a more targeted and reliable basis for determining the recoverable resources in the appraisal area.

[0068] Step S104: Determine the recoverable resources in the evaluation area based on the estimated cumulative production, actual reservoir drilling rate, and actual length of the horizontal section.

[0069] Specifically, based on the estimated cumulative production of appraisal wells, the actual reservoir drilling rate, and the actual length of the horizontal section, the recoverable resources in the appraisal area can be further analyzed and predicted. Since the determination of recoverable resources includes relevant data from actual drilled appraisal wells, the accuracy and reliability of the appraisal results can be guaranteed to a great extent.

[0070] In summary, the method for evaluating recoverable resources in tight oil reservoirs provided in this application, by obtaining the actual production of appraisal wells in the initial stage, can further determine the estimated cumulative production of appraisal wells based on the actual production of appraisal wells in the initial stage, and combine this with the actual reservoir encounter rate and the actual length of the horizontal section of the appraisal well to determine the recoverable resources in the evaluation area. Since the appraisal wells are drilled horizontal wells located within the evaluation area, the relevant data from the appraisal wells can more accurately reflect the actual situation in the evaluation area, improving the pertinence and accuracy of the evaluation of recoverable resources in the evaluation area. Furthermore, since the appraisal wells have completed the actual production in the initial stage, it is possible to obtain highly accurate initial stage actual production, actual reservoir encounter rate, and actual length of the horizontal section of the appraisal wells. This ensures the accuracy of the estimated cumulative production of the appraisal wells and significantly improves the accuracy of the evaluation of recoverable resources in the evaluation area, providing a more accurate and reliable reference for subsequent development work in the evaluation area and enhancing the economy and efficiency of tight oil reservoir development.

[0071] In some examples, the steps for determining the estimated cumulative production of an appraisal well based on the actual production at the initial stage include:

[0072] To obtain the production rate at each stage of the calibration well, the calibration well is a tight oil horizontal well in the calibration zone;

[0073] Based on the actual production in the initial stage and the production at the stage calibration, determine the expected production of the appraisal well in that stage;

[0074] The estimated cumulative output is determined based on the actual output in the initial stage and the projected output for the stage.

[0075] Specifically, a calibration well is a tight oil horizontal well within a calibration zone. The stage calibration production of a calibration well refers to the actual production of the calibration well at the corresponding production stage. By obtaining the stage calibration production of the calibration well, the production pattern of the calibration well can be obtained. Then, by combining this with the actual production of the appraisal well in its initial stage, the production pattern of the appraisal well can be estimated by analogy between the appraisal well and the calibration well, thus obtaining the stage-based projected production of the appraisal well. It can be understood that the stage-based projected production of the appraisal well refers to the projected production of the appraisal well in the production stages excluding the initial stage. Furthermore, based on the actual initial stage production and stage-based projected production of the appraisal well, the estimated cumulative production of the appraisal well can be determined. This achieves the determination of the estimated cumulative production of the appraisal well based on the actual production of the calibration well and the actual production of the appraisal well in its initial stage, ensuring the numerical reliability of the estimated cumulative production and further guaranteeing the reliability of the recoverable resource assessment results of the appraisal zone.

[0076] It is understandable that the calibration wells used in the aforementioned process can be tight oil horizontal wells within the calibration area that have undergone actual production for a considerable period of time, thereby further ensuring the richness of data on stage calibration production. Furthermore, to further improve the reliability of estimated cumulative production, when selecting calibration areas, tight oil reservoir blocks with relatively high exploration levels, largely completed evaluation phases, relatively clear reservoir understanding, relatively complete production well locations, full-scale development, and high consistency between geological characteristics and the evaluation area can be selected as calibration areas.

[0077] In some examples, the steps for determining the stage-expected production of an appraisal well based on the initial stage actual production and the stage calibration production include:

[0078] Determine the stage production scale decline rate of the calibrated well based on the production output at each stage.

[0079] The stage production decline rate is determined as the expected stage production decline rate of the appraisal well.

[0080] The stage-expected production of the appraisal well is determined based on the actual production in the initial stage and the expected production decline rate in the stage.

[0081] Specifically, the stage production decline rate of a calibration well refers to the rate of production reduction between two adjacent production stages of the calibration well. Based on the calibration production of each stage of the calibration well, the stage production decline rate of the calibration well can be determined one by one. Then, the stage production decline rate of the calibration area is used as the stage production expected decline rate of the appraisal well. Combined with the actual production of the appraisal well in the initial stage, the stage expected production of each production stage of the appraisal well in the future can be calculated. This ensures that the production estimation of the appraisal well meets the production decline law, further improving the accuracy and reliability of the prediction of the stage expected production and the estimated cumulative production of the appraisal well, and enhancing the accuracy and authenticity of the evaluation of the recoverable resources in the appraisal area.

[0082] In some examples, the number of appraisal wells is greater than or equal to one.

[0083] Specifically, in the process of evaluating the recoverable resources in the evaluation area, one or more appraisal wells can be used. Using multiple appraisal wells can further enrich the data related to these wells, providing more data samples for estimating recoverable resources, thereby further improving the accuracy and relevance of the evaluation of recoverable resources in the evaluation area.

[0084] In some examples, the steps for determining the recoverable resources of an evaluation zone based on estimated cumulative production, actual reservoir encounter rate, and actual horizontal segment length include:

[0085] Obtain the horizontal well spacing in the evaluation area. The horizontal wells in the evaluation area include planned development wells and evaluation wells. The planned development wells are the horizontal wells to be drilled located in the evaluation area.

[0086] Obtain the estimated reservoir encounter rate in the evaluation area;

[0087] Obtain the effective oil-bearing area of ​​the evaluation zone;

[0088] The recoverable resources are determined based on the horizontal well spacing, estimated reservoir encounter rate, effective oil-bearing area, estimated cumulative production, actual reservoir encounter rate, and actual length of the horizontal section; or

[0089] Obtain the degree of well control of the horizontal wells in the evaluation area;

[0090] The recoverable resources are determined based on the horizontal well spacing, estimated reservoir encounter rate, effective oil-bearing area, estimated cumulative production, actual reservoir encounter rate, actual length of horizontal section, and well control degree of horizontal wells.

[0091] Specifically, the horizontal wells in the evaluation area include evaluation wells and planned development wells. Planned development wells refer to horizontal wells located in the evaluation area that are yet to be drilled, i.e., horizontal wells that are still in the well network planning stage but have not yet been drilled or are awaiting drilling. The horizontal well spacing in the evaluation area can be obtained based on the well network planning information of the evaluation area. At the same time, the estimated reservoir encounter rate and effective oil-bearing area of ​​the evaluation area are obtained. Combined with the estimated cumulative production of evaluation wells, the actual reservoir encounter rate, and the actual length of the horizontal section, the recoverable resources in the evaluation area are comprehensively analyzed and determined. Thus, in the process of evaluating recoverable resources, the well network planning and reservoir distribution of the evaluation area are further considered, which further ensures the integrity and comprehensiveness of the evaluation process and improves the accuracy of the recoverable resources evaluation results.

[0092] It should be noted that the estimated reservoir encounter rate in the evaluation area refers to the average reservoir encounter rate of all horizontal wells in the evaluation area.

[0093] In the case of one appraisal well, the formula for determining the recoverable resources based on the horizontal well spacing, estimated reservoir penetration rate, effective oil-bearing area, estimated cumulative production, actual reservoir penetration rate, and actual length of the horizontal section is as follows:

[0094]

[0095] In the formula, Q represents the recoverable resource quantity, in units of 10. 4 t; Estimated cumulative production of the evaluation well, in units of 10. 4 t; The actual reservoir encounter rate of the appraisal well; Risk is the estimated reservoir encounter rate of the appraisal area; A is the effective oil-bearing area of ​​the appraisal area, in km². 2 ; H represents the actual length of the horizontal section of the evaluation well, in km; H represents the horizontal well spacing in the evaluation area, in km.

[0096] When there are multiple appraisal wells, the formula for determining the recoverable resources based on the horizontal well spacing, estimated reservoir penetration rate, effective oil-bearing area, estimated cumulative production, actual reservoir penetration rate, and actual length of the horizontal section is as follows:

[0097]

[0098] In the formula, The estimated cumulative production of the i-th appraisal well, in units of 10. 4 t; The actual reservoir encounter rate of the i-th appraisal well; is the actual length of the horizontal section of the i-th evaluation well, in km; n is the number of horizontal wells.

[0099] Simultaneously, the well control degree of horizontal wells in the evaluation area can be further obtained, and combined with the horizontal well spacing, estimated reservoir drilling rate, effective oil-bearing area, estimated cumulative production, actual reservoir drilling rate, and actual length of the horizontal section, the recoverable resources in the evaluation area can be determined. Thus, in the process of evaluating recoverable resources, the difference between the controlled area and the effective oil-bearing area of ​​the horizontal wells in the evaluation area can be further considered, thereby improving the accuracy of the recoverable resources evaluation results.

[0100] In the case of one appraisal well, the formula for determining the recoverable resources based on the horizontal well spacing, estimated reservoir penetration rate, effective oil-bearing area, estimated cumulative production, actual reservoir penetration rate, actual length of the horizontal section, and well control degree of the horizontal well is as shown in equation (3):

[0101]

[0102] In the formula, K represents the degree of well control of the evaluation area and is a percentage.

[0103] When there are multiple appraisal wells, the formula for determining the recoverable resources based on the horizontal well spacing, estimated reservoir penetration rate, effective oil-bearing area, estimated cumulative production, actual reservoir penetration rate, actual length of the horizontal section, and well control degree of the horizontal wells is as shown in equation (4):

[0104]

[0105] In some examples, the steps for obtaining the horizontal well spacing of the evaluation area include:

[0106] Obtain fracturing monitoring data from the appraisal well;

[0107] The horizontal well spacing is determined based on fracturing monitoring data.

[0108] Specifically, before an appraisal well is put into production, it must be fracturing and the fracturing effect must be monitored in real time. The horizontal well spacing in the appraisal area can be determined based on the fracturing monitoring data of the appraisal well, and the fracturing monitoring data is measured data, which further ensures the reliability of the determination of the horizontal well spacing.

[0109] Understandably, the fracturing monitoring data of appraisal wells includes the fracture plane length. The distribution range of the fracture plane length can be used as the selectable range for the horizontal well spacing, and numerical simulation tests or simulation analysis can be conducted accordingly to determine the optimal horizontal well spacing from the selectable range.

[0110] In some examples, the steps for obtaining the estimated reservoir encounter rate for the evaluation zone include:

[0111] The reference reservoir encounter rate of multiple reference wells is obtained. The reference wells are drilled horizontal wells located in the reference area, and the reference area and the evaluation area are located in the same region.

[0112] Determine the average drilling rate of multiple reference reservoirs;

[0113] The mean drilling rate is used to estimate the reservoir drilling rate.

[0114] Specifically, reference wells are drilled horizontal wells located in the reference area, which is situated in the same region as the evaluation area. The reference reservoir encounter rate refers to the actual reservoir encounter rate of the reference wells. By obtaining the reference reservoir encounter rates of multiple reference wells and using the average of these rates as the estimated reservoir encounter rate for the evaluation area, the estimated reservoir encounter rate for the evaluation area can be obtained before the completion of all horizontal wells, thus significantly reducing the cost of evaluating recoverable resources. Furthermore, since the reference area and evaluation area are located in the same region, their geological characteristics and reservoir distribution are highly similar. The average of the encounter rates of multiple reference reservoirs provides a reliable reference for the estimated reservoir encounter rate in the evaluation area, ensuring high accuracy in the estimated reservoir encounter rate.

[0115] In some examples, the steps for obtaining the level of well control in the evaluation area include:

[0116] Obtain the total number of horizontal wells in the evaluation area;

[0117] Obtain the average well control area per well in the evaluation area;

[0118] The total well-controlled area of ​​the evaluation area is determined based on the total number of horizontal wells and the average well-controlled area per well in the evaluation area.

[0119] The degree of well control of the horizontal wells in the evaluation area is determined based on the total well-controlled area and the effective oil-bearing area of ​​the evaluation area.

[0120] Specifically, by obtaining the total number of horizontal wells and the average well-controlled area per well in the evaluation area, the total well-controlled area of ​​the evaluation area can be determined. Then, combined with the effective oil-bearing area of ​​the evaluation area, the well-controlled degree of the horizontal wells in the evaluation area can be determined. In the process of evaluating recoverable resources, the well-controlled degree of the horizontal wells in the evaluation area can be further combined to improve the accuracy of the evaluation of recoverable resources.

[0121] It should be noted that in actual production, the total well-controlled area is usually smaller than the effective oil-bearing area, that is, the well control degree is often less than 1. Non-well-controlled areas are usually areas near faults, lithological edges, oil-bearing dead zones, etc. In the process of evaluating recoverable resources, the well control degree of horizontal wells in the evaluation area is considered, and the aforementioned non-well-controlled areas can be excluded, thereby further improving the accuracy of recoverable resource evaluation.

[0122] In some examples, the steps for obtaining the average well-controlled area per well in the evaluation zone include:

[0123] Obtain the planned length of the horizontal section of the development well;

[0124] The average length of a single well horizontal section in the evaluation area is determined based on the planned length and the actual length of the horizontal section.

[0125] The average well-controlled area per well is determined based on the average length of the horizontal section of a single well and the horizontal well spacing in the evaluation area.

[0126] Specifically, by obtaining the planned length of the horizontal section of the development well, and combining it with the actual length of the horizontal section of the appraisal well, the average length of the horizontal section per well in the appraisal area can be determined. Furthermore, by combining this with the horizontal well spacing in the appraisal area, the average well-controlled area per well in the appraisal area can be further determined. This provides a basis for determining the degree of well control of the horizontal wells in the appraisal area and for evaluating recoverable resources, thus improving the accuracy and reliability of the recoverable resource evaluation results. Moreover, the horizontal well spacing in the appraisal area is determined based on the fracturing monitoring data of the appraisal wells, making the determination of the horizontal well spacing more closely integrated with the actual implementation effect of the appraisal wells, and resulting in a more accurate and reliable determination of the average well-controlled area per well.

[0127] As an example of the method for evaluating the recoverable resources of tight oil reservoirs proposed in this application, the method can be carried out in practical applications according to the following steps, including:

[0128] Step S11: Based on the reservoir stimulation and fracturing monitoring results, estimate the horizontal well spacing or average single-well controlled area of ​​the evaluation zone;

[0129] Step S12: Estimate the effective oil-bearing area of ​​the evaluation zone based on the comprehensive reservoir evaluation technology;

[0130] Step S13: Based on geological characteristics, average effective thickness of a single layer, and drilling guidance technology, comprehensively evaluate the estimated reservoir drilling rate of the evaluation area;

[0131] Step S14: Obtain the average value of the evaluation wells through analogy.

[0132] Step S15: Calculate the amount of recoverable resources in the evaluation area.

[0133] Specifically, taking the assessment of recoverable resources of the Shugu 169 block's Sha-4 lower Gaosheng tight oil reservoir as an example, a test was previously conducted on the Shugu 169 old well's Shugu 169 Sha-4 lower Gaosheng oil layer (3089.0-3158.1m), with a daily oil production of 6.25t, and the test concluded that it was an oil layer. The evaluation of fracturing stimulation and trial production achieved good results, with a cumulative oil production of 5454 tons, meeting the standards for reporting newly proven reserves.

[0134] Based on the successful oil testing and production at the old well, a comprehensive geological study was conducted on the block. The study concludes that the Shugu 169 block of the Shuguang Oilfield, specifically the Gaosheng tight reservoir below the Sha-4 level, is a dual-medium medium reservoir type (porosity and fracture). The average effective porosity of the reservoir is 5.0%, and the average permeability is 40 mD, classifying it as a low-porosity to medium-permeability reservoir. The oil layer distribution in the Shugu 169 block is controlled by lithology and faults, generally trending northeast. The thickest areas are in the Shugu 183-Shugu 107 area, with thicknesses exceeding 20 m, thinning towards the northwest-southwest direction. The reservoir depth is 2480-3600 m, and the reservoir type is lithological. The block is controlled by early faults (paleogeography), and the favorable lithology of argillaceous dolomite is concentrated in northeast-trending bands: relatively stable thick layers of 15-20 m develop in the upper part, extending along the bands and thinning towards both ends; localized oil layers develop at the bottom, with a thickness of 2-3 m; effective reservoirs are not developed outside the bands. The crude oil is generally classified as a light oil, with relatively high viscosity and a relatively high pour point. Based on the comprehensive reservoir evaluation technology, the effective oil-bearing area of ​​the Shugu 169 block's Sha-4 lower high-rise oil reservoir is estimated to be 4.19 km². 2 .

[0135] Based on the successful oil testing and fracturing at Shugu 169, a total of four subsequent rolling exploration wells (Shugu 169-1, Shugu 169-2, Shugu 169-3, and Shugu 169-4) were drilled. All four wells underwent fracturing, initially producing 60 tons of oil per day, with a cumulative production of 6778 tons. The implementation of these rolling exploration wells has essentially confirmed the regional structural characteristics, reservoir features, and oil layer distribution. Drilling, logging, and well logging data have verified the understanding of the geological bodies, laying the foundation for the evaluation of the regional oil reservoir potential.

[0136] The upper part of the reservoir in this region is characterized by concentrated oil layers of 15-20m, with virtually no interlayers within. The formation has low clay content, indicating strong fracturing and fracture-creating capabilities. Based on these geological characteristics, the first appraisal well in the region, Shugu 169-Gao H1, was drilled to assess the reservoir's potential. The Shugu 169-Gao H1 well reached a total depth of 3808m, with a horizontal section length of 400m, encountering 340m of reservoir, representing an actual reservoir encounter rate of 85%. The well underwent multi-stage cluster perforation fracturing operations, with perforated sections ranging from 3300-3755m. During the fracturing process, in-well microseismic fracturing monitoring technology was used to monitor the fracturing and fracture-creating effect in real time. The monitored fracture network measured 210-335m in length, 55-99m in width, and 41-62m in height, with a total monitored reservoir stimulation volume of 7.84 million cubic meters. Based on the actual fracture monitoring results and referring to numerical simulation results, the horizontal well spacing was determined to be 200m. Based on this, the well network and spacing of the Shugu 169 block Sha-4 lower Gaosheng tight oil reservoir were planned, and the horizontal well control rate was determined to be 90%. Furthermore, using the reservoir encounter rates of several drilled horizontal wells in similar blocks in the local area of ​​the Shugu 169 block Sha-4 lower Gaosheng tight oil reservoir as a reference reservoir encounter rate, the estimated reservoir encounter rate of the Shugu 169 block Sha-4 lower Gaosheng tight oil reservoir was determined to be 0.9, or 90%. Meanwhile,

[0137] The Shugu 169-Gao H1 well began production with a daily oil yield of 23.6 tons in the initial stage, and an annual verified oil yield of 2,000 tons. Using the first-year oil yield of the Shugu 169-Gao H1 well as the initial actual production, and through analogy, referencing the declining production pattern of horizontal tight oil wells in the Chang 7 tight oil well of the Yanchang Formation in the Ordos Basin, and using the Yangping 2 well as a calibration well, the estimated results are shown in Table 1.

[0138]

[0139] Table 1

[0140] Based on the results in Table 1, the estimated cumulative production of the Shugu 169-Gao H1 well is 18,800 tons.

[0141] According to equation (3), the recoverable resources of the Shugu 169 block Sha-4 lower Gaosheng tight oil reservoir are calculated to be 730,000 tons. The recoverable resources and technically recoverable reserves of the block are similar, proving the reliability and feasibility of this evaluation method. The accurate evaluation of recoverable resources provides a theoretical basis and reference for the implementation of subsequent development wells in the block.

[0142] The evaluation of the Shugu 169 block Shasixia Gaosheng tight oil reservoir also involved the exploration practice of tight oil reservoirs. The comprehensive exploration method for tight oil reservoirs can be summarized as a four-step strategy:

[0143] Step S21: Test the old well to find new layers.

[0144] Specifically, the target strata encountered by the old wells in the area are Proterozoic strata. The high-yield oil layer below the Guolusha No. 4 layer shows good oil content, with obvious typical curve response characteristics. Under the premise that the production capacity of the target layer has declined and cannot reach the daily oil production standard, oil testing and production trials are conducted on the Guolusha No. 4 layer to evaluate reservoir characteristics, determine the oil layer potential, and explore the potential for increasing reserves in new layers.

[0145] Step S22: Conduct a comprehensive study of the geological body.

[0146] Specifically, after the production potential of new formations in old wells has been largely realized, a comprehensive study of the regional geological bodies will be conducted. This study will primarily utilize stratigraphic correlation, detailed seismic interpretation, and data from regional old well trials and coring. Based on the established geological characteristics, including paleogeomorphology and sedimentary patterns, structural features, reservoir characteristics, sand body distribution patterns, favorable lithology, and the distribution range of favorable reservoirs, various maps reflecting the characteristics of the high-yield oil-bearing geological bodies in the region will be drawn (including structural maps, favorable lithology distribution maps, and oil layer distribution maps).

[0147] Step S23: Implement rolling exploration wells to confirm the area boundary.

[0148] Specifically, based on a comprehensive study of the geological body, rolling exploration wells are implemented to verify and confirm the characteristics of the regional reservoir. Various data obtained from drilling, logging, and well logging (cores, curves, pressure, temperature, etc.) are used to verify the geological features, further improve the understanding of the geological body, and determine the distribution range of favorable reservoirs.

[0149] Step S24: Horizontal well evaluation of reservoir potential.

[0150] Specifically, given the basic characteristics of the reservoir and the distribution range of favorable reservoir layers, the geological reserves of the reservoir are calculated using the volumetric method and the analogy method. The Gaosheng oil layer has a single layer thickness of approximately 20 meters, a relatively stable and uniform distribution, making it suitable for horizontal well development. Evaluation horizontal wells are implemented in structurally favorable locations. Due to the poor physical properties of tight reservoirs, cluster perforation fracturing technology in horizontal wells can expand the effective seepage range of the reservoir, improve seepage efficiency, and increase single-well productivity. During fracturing operations, in-well microseismic fracturing monitoring technology is used to monitor the fracturing effect in real time. Based on the monitoring results, the effective oil-bearing range controllable by a single well is ultimately determined, thereby determining the average well-controlled area per well. This further allows for the calculation of the overall recoverable resources of the region, providing a deployment basis for the implementation of subsequent development wells.

[0151] According to a second aspect of the embodiments of this application, a device 200 for evaluating the recoverable resources of tight oil reservoirs is provided, such as... Figure 2 As shown, it includes:

[0152] The first acquisition module 201 is used to acquire the initial stage actual production of the appraisal well, which is a drilled horizontal well located in the appraisal area.

[0153] The first determining module 202 is used to determine the estimated cumulative production of the appraisal well based on the actual production in the initial stage;

[0154] The second acquisition module 203 is used to acquire the actual reservoir drilling rate and the actual length of the horizontal section of the appraisal well.

[0155] The second determination module 204 is used to determine the recoverable resources in the evaluation area based on the estimated cumulative production, the actual reservoir drilling rate, and the actual length of the horizontal section.

[0156] The tight oil reservoir recoverable resource evaluation device provided in this application obtains the actual production of the appraisal well in the initial stage. Based on this initial stage production, it can further determine the estimated cumulative production of the appraisal well and, combined with the actual reservoir encounter rate and the actual length of the horizontal section, determine the recoverable resources of the evaluation area. Since the appraisal well is a drilled horizontal well located within the evaluation area, its data can more accurately reflect the actual situation of the evaluation area, improving the relevance and accuracy of the recoverable resource evaluation. Furthermore, the appraisal well has completed its initial stage of actual production, enabling the acquisition of highly accurate initial stage production, actual reservoir encounter rate, and actual length of the horizontal section. This ensures the accuracy of the estimated cumulative production of the appraisal well and significantly improves the accuracy of the recoverable resource evaluation of the evaluation area. This provides a more accurate and reliable reference for subsequent development work in the evaluation area, enhancing the economy and efficiency of tight oil reservoir development.

[0157] In some feasible examples, the first determining module 202 includes:

[0158] The first acquisition unit is used to acquire the production rate of each stage of the calibration well, which is a tight oil horizontal well in the calibration zone;

[0159] The first determining unit is used to determine the stage-expected production of the appraisal well based on the actual production in the initial stage and the stage-calibrated production.

[0160] The second determining unit is used to determine the estimated cumulative output based on the actual output in the initial stage and the projected output in the stage.

[0161] In some feasible examples, the first determining unit includes:

[0162] The first determining sub-unit is used to determine the stage production scale reduction rate of the scale well based on the scale production of each stage.

[0163] The second determining sub-unit is used to determine the stage production scale decline rate as the expected stage production decline rate of the appraisal well;

[0164] The third determining sub-unit is used to determine the stage-expected production of the appraisal well based on the initial stage actual production and the stage production expected decline rate.

[0165] In some feasible examples, the number of evaluation wells is greater than or equal to one.

[0166] In some feasible examples, the second determining module 204 includes:

[0167] The second acquisition unit is used to acquire the horizontal well spacing in the evaluation area. The horizontal wells in the evaluation area include planned development wells and evaluation wells. The planned development wells are horizontal wells to be drilled located in the evaluation area.

[0168] The third acquisition unit is used to acquire the estimated reservoir drilling rate in the evaluation area;

[0169] The fourth acquisition unit is used to acquire the effective oil-bearing area of ​​the evaluation zone;

[0170] The third determining unit is used to determine the recoverable resources based on the horizontal well spacing, estimated reservoir encounter rate, effective oil-bearing area, estimated cumulative production, actual reservoir encounter rate, and actual length of the horizontal section; or

[0171] The fifth acquisition unit is used to acquire the degree of well control of the horizontal wells in the evaluation area;

[0172] The fourth determination unit is used to determine the recoverable resources based on the horizontal well spacing, estimated reservoir penetration rate, effective oil-bearing area, estimated cumulative production, actual reservoir penetration rate, actual length of the horizontal section, and well control degree of the horizontal well.

[0173] In some feasible examples, the second acquisition unit includes:

[0174] The first acquisition subunit is used to acquire fracturing monitoring data from the evaluation well;

[0175] The fourth determination subunit is used to determine the horizontal well spacing based on fracturing monitoring data.

[0176] In some feasible examples, the third acquisition unit includes:

[0177] The second acquisition subunit is used to acquire the reference reservoir drilling rate of multiple reference wells. The reference wells are drilled horizontal wells located in the reference area, and the reference area and the evaluation area are located in the same region.

[0178] The fifth determination sub-unit is used to determine the average drilling rate of multiple reference reservoirs;

[0179] The sixth determination sub-unit is used to determine the mean drilling rate as the estimated reservoir drilling rate.

[0180] In some feasible examples, the fifth acquisition unit includes:

[0181] The third acquisition subunit is used to acquire the total number of horizontal wells in the evaluation area;

[0182] The fourth acquisition subunit is used to acquire the average well-controlled area per well in the evaluation area;

[0183] The seventh sub-unit is used to determine the total well-controlled area of ​​the evaluation area based on the total number of horizontal wells and the average well-controlled area per well in the evaluation area.

[0184] The eighth determination sub-unit is used to determine the degree of well control of horizontal wells in the evaluation area based on the total well-controlled area and the effective oil-bearing area of ​​the evaluation area.

[0185] In some feasible examples, the fourth acquisition subunit includes:

[0186] The component is used to obtain the planned length of the horizontal segment of the planned development well.

[0187] The first determining component is used to determine the average single-well horizontal section length of the evaluation area based on the planned length and actual length of the horizontal section.

[0188] The second determining component is used to determine the average well-controlled area per well based on the average horizontal section length of a single well and the horizontal well spacing in the evaluation area.

[0189] According to a third aspect of the embodiments of this application, a storage medium is provided, the storage medium including a stored program, wherein, when the program is running, the device where the storage medium is located is controlled to execute the method as described in any of the first aspects above.

[0190] According to a fourth aspect of the embodiments of this application, an electronic device 300 is provided, such as... Figure 3 As shown, the electronic device 300 includes at least one processor 301 and at least one memory 302 connected to the processor 301, wherein the processor 301 is used to call program instructions in the memory 302 to execute the method as proposed in any of the first aspects above.

[0191] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus, and electronic devices according to embodiments of this application; it should 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 process management device to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable process management device, generate instructions for implementing the process Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0192] In the above embodiments, the descriptions of each embodiment have different focuses. For parts not described in detail in a certain embodiment, please refer to the relevant descriptions in other embodiments.

[0193] In the several embodiments provided in this application, it should be understood that the disclosed apparatus can be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative; for instance, the division of the units described above is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be through some interfaces; the indirect coupling or communication connection between devices or units may be electrical or other forms.

[0194] In a typical configuration, an electronic device may include one or more processors (CPUs), memory, and buses; the electronic device may also include input / output interfaces, network interfaces, etc.

[0195] The memory may include non-permanent memory in a computer-readable medium, such as random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash RAM, and the memory includes at least one memory chip; the memory is an example of a storage medium.

[0196] Storage media, including permanent and non-permanent, removable and non-removable media, can be used to store information by any method or technology; the information can be computer-readable instructions, data structures, program modules, or other data; examples of computer storage media include, but are not limited to, phase-change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technologies, CD-ROM, digital versatile optical disc (DVD) or other optical storage, magnetic tape, magnetic disk storage or other magnetic storage devices, or any other non-transferable medium that can be used to store information that can be accessed by a computing device; as defined herein, storage media does not include transient media, such as modulated data signals and carrier waves.

[0197] The terms “first,” “second,” “third,” “fourth,” etc. (if present) in the specification, claims, and drawings of this application are used to distinguish similar objects and are not necessarily used to describe a particular order or sequence; it should be understood that such data used can be interchanged where appropriate so that the embodiments described herein can be implemented in a sequence other than that illustrated or described herein.

[0198] It should be noted that, for the sake of simplicity, the foregoing method embodiments are all described as a series of actions. However, those skilled in the art should understand that this application is not limited to the described order of actions, as some steps may be performed in other orders or simultaneously according to this application. Furthermore, those skilled in the art should also understand that the embodiments described in the specification are preferred embodiments, and the actions and modules involved are not necessarily essential to this application.

[0199] It should also be noted that the terms “comprising,” “including,” or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such process, method, article, or apparatus; and, without further limitation, an element defined by the phrase “comprising one…” does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes the element.

[0200] Those skilled in the art will understand that embodiments of this application can be provided as methods, apparatus, or electronic devices; therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects; moreover, this application can take 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 code.

[0201] Computer program code for performing the operations of the embodiments of this application can be written in one or more programming languages ​​or a combination thereof. Programming languages ​​include object-oriented programming languages ​​such as Common Lisp, Python, C++, Objective-C, Smalltalk, Delphi, Java, Swift, C#, Perl, Ruby, JavaScript, and PHP; conventional procedural programming languages ​​such as Fortran, ALGOL, COBOL, PL / I, BASIC, Pascal, and C; and any other programming language such as Lisp, Tcl, Prolog, Visual Basic .NET, SQL, and R. The program code can be executed entirely on the user's computer, partially on the user's computer, as a standalone software package, partially on the user's computer and partially on a remote computer, or entirely on a remote computer or server. In cases involving remote computers, the remote computer can be connected to the user's computer via any type of network—including a local area network (LAN) or a wide area network (WAN)—or can be connected to an external computer (e.g., via the Internet using an Internet service provider).

[0202] The above embodiments are only used to illustrate the technical solutions of this application, and are not intended to limit them. Although this application has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features. Such modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of this application, and should all be included within the scope of the claims of this application.

Claims

1. A method for evaluating the recoverable resources of tight oil reservoirs, characterized in that, include: Obtain the initial stage actual production of the appraisal well, which is a drilled horizontal well located within the appraisal area; Based on the actual production in the initial stage, determine the estimated cumulative production of the appraisal well; Obtain the actual reservoir encounter rate and the actual length of the horizontal section of the evaluation well; The recoverable resources of the evaluation area are determined based on the estimated cumulative production, the actual reservoir encounter rate, and the actual length of the horizontal section. The step of determining the estimated cumulative production of the appraisal well based on the actual production in the initial stage includes: Obtain the production rate at each stage of the calibration well, wherein the calibration well is a tight oil horizontal well in the calibration zone; Based on the actual production in the initial stage and the production at the stage calibration, determine the expected production of the appraisal well at that stage; The estimated cumulative output is determined based on the actual output of the initial stage and the projected output of the stage; The step of determining the recoverable resources of the evaluation area based on the estimated cumulative production, the actual reservoir encounter rate, and the actual length of the horizontal segment includes: Obtain the horizontal well spacing in the evaluation area, wherein the horizontal wells in the evaluation area include planned development wells and the evaluation wells, and the planned development wells are horizontal wells to be drilled located in the evaluation area; Obtain the estimated reservoir encounter rate for the evaluation area; Obtain the effective oil-bearing area of ​​the evaluation region; The recoverable resources are determined based on the horizontal well spacing, the estimated reservoir encounter rate, the effective oil-bearing area, the estimated cumulative production, the actual reservoir encounter rate, and the actual length of the horizontal section; or Obtain the well control level of the horizontal wells in the evaluation area; The recoverable resources are determined based on the horizontal well spacing, the estimated reservoir encounter rate, the effective oil-bearing area, the estimated cumulative production, the actual reservoir encounter rate, the actual length of the horizontal section, and the well control level of the horizontal well.

2. The method for evaluating recoverable resources in tight oil reservoirs according to claim 1, characterized in that, The step of determining the stage-expected production of the appraisal well based on the initial stage actual production and the stage-calibrated production includes: Based on the production output at each stage, determine the stage production output reduction rate of the calibrated well; The stage production scale decline rate is determined to be the stage production expected decline rate of the appraisal well; The stage-expected production of the appraisal well is determined based on the actual production in the initial stage and the expected production decline rate in the stage.

3. The method for evaluating recoverable resources in tight oil reservoirs according to claim 2, characterized in that, The number of evaluation wells is greater than or equal to one.

4. The method for evaluating the recoverable resources of tight oil reservoirs according to any one of claims 1 to 3, characterized in that, The step of obtaining the horizontal well spacing of the evaluation area includes: Obtain the fracturing monitoring data of the evaluation well; The horizontal well spacing is determined based on the fracturing monitoring data.

5. The method for evaluating recoverable resources in tight oil reservoirs according to claim 1, characterized in that, The step of obtaining the estimated reservoir encounter rate for the evaluation area includes: Obtain the reference reservoir encounter rate of multiple reference wells, wherein the reference wells are drilled horizontal wells located in the reference area, and the reference area and the evaluation area are located in the same region; Determine the average drilling rate of multiple reference reservoirs; The mean drilling rate is determined to be the estimated reservoir drilling rate.

6. The method for evaluating recoverable resources in tight oil reservoirs according to claim 1, characterized in that, The step of obtaining the well control degree of the horizontal well in the evaluation area includes: Obtain the total number of horizontal wells in the evaluation area; Obtain the average well control area per well in the evaluation area; The total well-controlled area of ​​the evaluation area is determined based on the total number of horizontal wells in the evaluation area and the average well-controlled area per well. The well control level of the horizontal wells in the evaluation area is determined based on the total well-controlled area and the effective oil-bearing area of ​​the evaluation area.

7. The method for evaluating recoverable resources in tight oil reservoirs according to claim 6, characterized in that, The step of obtaining the average well-controlled area per well in the evaluation area includes: Obtain the planned length of the horizontal section of the planned development well; The average length of a single well horizontal segment in the evaluation area is determined based on the planned length and the actual length of the horizontal segment. The average well-controlled area per well is determined based on the average horizontal section length of a single well and the horizontal well spacing of the evaluation area.

8. A device for evaluating the recoverable resources of tight oil reservoirs, characterized in that, include: The first acquisition module is used to acquire the actual production of the appraisal well in the initial stage, wherein the appraisal well is a drilled horizontal well located in the appraisal area; The first determining module is used to determine the estimated cumulative production of the appraisal well based on the actual production in the initial stage; The second acquisition module is used to acquire the actual reservoir drilling rate and the actual length of the horizontal section of the evaluation well. The second determining module is used to determine the recoverable resources of the evaluation area based on the estimated cumulative production, the actual reservoir drilling rate, and the actual length of the horizontal segment. The first determining module includes: The first acquisition unit is used to acquire the production rate of each stage of the calibration well, which is a tight oil horizontal well in the calibration zone; The first determining unit is used to determine the stage-expected production of the appraisal well based on the actual production in the initial stage and the stage-calibrated production. The second determining unit is used to determine the estimated cumulative output based on the actual output in the initial stage and the projected output in the stage. The second determining module includes: The second acquisition unit is used to acquire the horizontal well spacing in the evaluation area. The horizontal wells in the evaluation area include planned development wells and evaluation wells. The planned development wells are horizontal wells to be drilled located in the evaluation area. The third acquisition unit is used to acquire the estimated reservoir drilling rate in the evaluation area; The fourth acquisition unit is used to acquire the effective oil-bearing area of ​​the evaluation zone; The third determining unit is used to determine the recoverable resources based on the horizontal well spacing, estimated reservoir encounter rate, effective oil-bearing area, estimated cumulative production, actual reservoir encounter rate, and actual length of the horizontal section; or The fifth acquisition unit is used to acquire the degree of well control of the horizontal wells in the evaluation area; The fourth determination unit is used to determine the recoverable resources based on the horizontal well spacing, estimated reservoir penetration rate, effective oil-bearing area, estimated cumulative production, actual reservoir penetration rate, actual length of the horizontal section, and well control degree of the horizontal well.

9. A storage medium, characterized in that, The storage medium includes a stored program, wherein the program, when running, controls the device on which the storage medium is located to perform the method as described in any one of claims 1 to 7.

10. An electronic device, characterized in that, The electronic device includes at least one processor and at least one memory connected to the processor, wherein the processor is configured to invoke program instructions in the memory to execute the method as described in any one of claims 1 to 7.

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