Horizontal well control sand body volume evaluation method based on geological engineering integration

Abstract

The invention provides a horizontal well control sand body volume evaluation method based on geological engineering integration, which comprises the following steps: step 1, based on geological engineering data, carrying out reservoir configuration unit division and boundary identification, and constructing a three-dimensional configuration distribution model and a sand mud model; step 2, based on the fracturing construction data, simulating a fracture by adopting an unconventional fracture network model to obtain fracture length and fracture height parameters of the fracturing fracture; step 3, carrying out production dynamic numerical simulation based on production dynamic data of the research area, and obtaining a horizontal well control area based on historical fitting and future production prediction of the well; step 4, based on fracture simulation and production dynamic numerical simulation, obtaining a three-dimensional volume controlled by the horizontal well; and 5, subtracting the mud volume obtained by the sand mud model from the three-dimensional volume controlled by the horizontal well to obtain the volume of the sand body controlled by the horizontal well. According to the method, multiple factors such as reservoir configuration, fracturing simulation and production dynamic simulation can be comprehensively considered, so that the volume of the control sand body of the horizontal well is calculated more accurately.

Description

Technical Field

[0001] The invention relates to the technical field of oil and gas field exploration and development, in particular to a method for evaluating the volume of sand bodies controlled by horizontal wells based on geological and engineering integration. Background Art

[0002] In the exploration and development of oil and gas fields, accurate estimation of the sand volume controlled by horizontal wells is crucial for planning effective development strategies and optimizing production processes. However, the evaluation methods used in the past have many limitations and are no longer able to meet the urgent need for high-precision data in current oil and gas field development.

[0003] In the past, the traditional way to evaluate the volume of sand bodies was mainly based on data obtained from geological exploration, using geological modeling and reservoir prediction technology to infer the distribution range and scale of sand bodies. However, a significant drawback of this method is that it often simplifies the complex and uneven characteristics of the reservoir, resulting in a significant difference between the evaluation results and the actual situation. In addition, the traditional method has not fully incorporated the effects of hydraulic fracturing operations and dynamic changes in the production process, so it is insufficient in reflecting the actual control capabilities of horizontal wells.

[0004] In recent years, the rise of integrated geological and engineering technology has prompted the industry to explore the integration of knowledge and technology from multiple disciplines such as geology, engineering and production management, in order to more accurately evaluate the sand volume effectively controlled by horizontal wells. Despite this, the current integrated geological and engineering methods still face some challenges. In particular, how to achieve seamless integration and coordinated optimization of data between hydraulic fracturing simulation, production dynamic numerical simulation and geological cognition still faces technical problems to be solved.

[0005] Therefore, how to comprehensively consider multiple factors such as reservoir configuration, reservoir properties, hydraulic fracturing effects, and production dynamics, and establish an accurate and reliable method for obtaining the volume of sand bodies controlled by horizontal wells has become a technical problem that needs to be solved urgently in the current field of oil and gas field exploration and development. In response to the above problems, the present invention proposes a method for obtaining the volume of sand bodies controlled by horizontal wells based on geological and engineering integration. This method establishes a complete and effective evaluation system by comprehensively considering multiple factors such as reservoir configuration, reservoir properties, hydraulic fracturing effects, and production dynamics. Through the application of this method, the accurate calculation of the volume of sand bodies within the control range of horizontal wells can be achieved, providing reliable data support for oil and gas field development, which is helpful to optimize development plans, improve oil and gas recovery rates, and reduce development costs. Summary of the invention

[0006] The present invention provides a method for evaluating the controlled sand volume of a horizontal well based on geological engineering integration. The method can comprehensively consider factors such as reservoir configuration, fracturing simulation, and production dynamic numerical simulation, so as to more accurately calculate the controlled sand volume of the horizontal well. Through the implementation of the present invention, a more scientific and reliable basis can be provided for oil and gas field exploration and development, which is helpful to optimize the development plan, improve the oil and gas recovery rate, reduce the development cost, and promote the progress of oil and gas field exploration and development technology.

[0007] The present invention provides a method for evaluating the volume of a horizontal well controlled sand body, comprising the following steps: Step S1, based on geological engineering data, reservoir configuration unit division and boundary identification are performed to construct a three-dimensional configuration distribution model and a sand-mud model; Step S2, based on the fracturing construction data, using the unconventional fracture network model UFM, simulates the fractures to obtain fracture length and fracture height parameters of the fractures; Step S3, based on the production dynamic data of the study area, simulate the production dynamic value, and obtain the horizontal well control area based on the historical fitting and future production prediction of each well; Step S4, obtaining a three-dimensional volume controlled by the horizontal well based on fracture simulation and production performance numerical simulation; Step S5, obtaining the volume of sand body controlled by the horizontal well by subtracting the mud volume obtained by the sand-mud model from the three-dimensional volume controlled by the horizontal well.

[0008] Furthermore, the geological engineering data includes basic geological data, and the basic geological data includes geological stratification data, well logging data and / or sand and mud interpretation data.

[0009] Furthermore, the geological engineering data also includes fracturing construction data, and the fracturing construction data includes perforation data, sand addition amount, liquid addition amount and / or displacement.

[0010] Furthermore, step 1 also includes: Step S11, establishing a well logging identification plate for configuration units according to the sedimentary facies type and configuration elements, and dividing each well in the study area into configuration units; Step S12, establishing a correlation equation between the length and width of each configuration unit based on the length and width distribution range of each configuration unit; Step S13, predicting the plane distribution range of the sand body by combining well and seismic data, based on the scale characteristics of the configuration units obtained by single well configuration analysis and field outcrop observation, and guided by the sedimentary model, characterizing the plane distribution characteristics of each configuration unit in the study area.

[0011] Step S14, identifying and dividing the configuration units of each well in the study area, and clarifying the dominant configuration units developed in each layer; Step S15, characterizing the range of the sand body based on the well-seismic data, identifying and characterizing the distribution scale and shape of the river channel within the sand body boundary; Step S16, defining the top and bottom interfaces of each river channel as two key levels to form a river channel configuration unit; Step S17, by identifying and depicting the top and bottom interfaces of the mid-shoal, a distribution model of the mid-shoal configuration unit is constructed inside the channel configuration unit.

[0012] Step S18, analyzing the core data of the coring well, and establishing a corresponding chart of sandstone and mudstone and the well logging curve; Step S19, using the sand-mud discrimination template, analyzing the single well logging data to identify and classify sandstone and mudstone; Step S20, under the constraint of the three-dimensional configuration distribution model, a three-dimensional sand and mud model is established based on the spatial relationship between wells and geological trends by using a sequential indicator simulation method.

[0013] Furthermore, step 2 also includes: Step S21, fitting the field perforation data and the fracturing pumping program; Step S22: Based on the geological model, an unconventional fracture network model UFM is used for simulation to obtain fracture length and fracture height parameters of the hydraulic fracture.

[0014] Furthermore, step 3 also includes: Step S31, collecting and collating the production dynamic data of the study area and coarsening the grid of the geological model; Step S32, starting the pressure gradient and stress sensitivity settings, setting the threshold pressure between two grid blocks to equivalently start the pressure gradient, and using the rock compression and expansion permeability multiplier table to characterize the stress sensitivity; Step S33, using the enumeration balance method to initialize the model and simulate the gas reservoir values ​​in the study area.

[0015] Furthermore, step 3 also includes: obtaining the vertical range of the sand body controllable by the horizontal well based on the fracture simulation, and obtaining the planar range controllable by the horizontal well based on the numerical simulation.

[0016] Furthermore, step 4 also includes: combining the vertical range of the sand body controlled by the horizontal well obtained based on the fracture simulation and the plane range of the sand body controlled by the horizontal well obtained by the numerical simulation to obtain the three-dimensional volume controlled by the horizontal well. The present invention significantly improves the accuracy and reliability of horizontal well controlled sand volume assessment by comprehensively using multiple technical means such as geological configuration analysis, fracturing simulation and production dynamic numerical simulation. The specific beneficial effects are: (1) The present invention comprehensively considers multiple factors such as reservoir configuration, reservoir physical properties, hydraulic fracturing effect and production dynamics, breaking the traditional limitation of relying solely on geological exploration data for evaluation, thereby greatly improving the accuracy of sand volume evaluation controlled by horizontal wells.

[0017] (2) Accurate control of sand body volume helps optimize oil and gas field development plans and effectively improve oil and gas recovery rates.

[0018] (3) This invention combines knowledge and technology from multiple fields such as geology, engineering and production, and promotes the development of integrated geology and engineering technology. This interdisciplinary methodology provides new ideas and technical means for oil and gas field exploration and development, and helps promote scientific and technological progress in the entire industry.

[0019] (4) The present invention is widely applicable to the exploration and development of various types of tight sandstone gas reservoirs, has strong adaptability and universality, and can be applied in different geological environments. BRIEF DESCRIPTION OF THE DRAWINGS

[0020] In order to more clearly illustrate the technical solutions in the present invention or the prior art, the following briefly introduces the drawings required for use in the embodiments or the description of the prior art. Obviously, the drawings described below are some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative work.

[0021] Figure 1 It is a flow chart of a method for evaluating the volume of sand bodies controlled by horizontal wells based on geological and engineering integration provided by an embodiment of the present invention.

[0022] Figure 2 It is a specific flow chart of step S1 in the horizontal well controlled sand body volume assessment method based on geological engineering integration provided in an embodiment of the present invention.

[0023] Figure 3 It is a specific flow chart of step S2 in the horizontal well controlled sand body volume assessment method based on geological engineering integration provided in an embodiment of the present invention.

[0024] Figure 4 It is a specific flow chart of step S3 in the horizontal well controlled sand body volume assessment method based on geological and engineering integration provided in an embodiment of the present invention.

[0025] Figure 5 It is a three-dimensional configuration layout model diagram of one embodiment of the present invention.

[0026] Figure 6 It is a diagram of crack simulation results of one embodiment of the present invention.

[0027] Figure 7 It is a residual pressure distribution and horizontal well control area diagram of one embodiment of the present invention.

[0028] Figure 8 This is a volume diagram of a sand body controlled by a horizontal well according to one embodiment of the present invention. DETAILED DESCRIPTION

[0029] In order to make the purpose, technical solution and advantages of the present invention clearer, the technical solution of the present invention will be clearly and completely described below in conjunction with the drawings of the present invention. Obviously, the described embodiments are part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the present invention.

[0030] Before describing the embodiments of the present application in detail, some nouns and terms involved in the embodiments of the present application are first described. The nouns and terms involved in the embodiments of the present application are subject to the following explanations.

[0031] The unconventional fracture network model (UFM) was proposed based on DFN. By establishing the fracture end extension criterion, factors such as the one-dimensional flow of fracturing fluid, the transport of proppant and the elastic deformation of fracture width are considered, and the interaction between adjacent artificial fractures is considered by calculating stress shadows.

[0032] The Beggs-Brill multiphase flow model is a method that can be used to calculate gas-liquid two-phase flow at horizontal, vertical and arbitrary inclination angles. It is a method with high accuracy and good adaptability currently used for multiphase flow calculation in inclined wells, directional wells and horizontal wells.

[0033] In the NTG model, the ratio of effective thickness to formation thickness is called net-to-gross ratio: NTG=Dznet / Dz, where Dznet represents effective thickness and Dz represents formation thickness. In the three-dimensional geological model of Petrel software, NTG usually refers to an invalid and effective reservoir distinguished by the numbers 0 and 1.

[0034] Rock compression expansion permeability multiplier table (ROCKTAB table). The ROCKTAB table has three columns of data. The first column represents the pressure, and it needs to be monotonically increasing when input; the second column is the pore volume multiplier corresponding to the pressure, and this multiplier represents the change of porosity with pressure; the third column is the conductivity multiplier corresponding to the pressure, and this multiplier represents the change of conductivity with pressure.

[0035] The pressure residual constrained CPR algorithm can usually effectively improve the robustness of isothermal reservoir simulation and the convergence speed of linear iteration.

[0036] The algebraic multigrid AMG algorithm is a fast iterative method for solving large linear algebraic equations. Unlike the geometric multigrid method (GMG), AMG does not require geometric grid information and only uses algebraic methods to construct multi-layer grids. The AMG algorithm is mainly divided into two stages: preparation and solution. In the preparation stage, the coefficient matrix is ​​operated by algebraic methods to generate multi-level rough coefficient matrices. In the solution stage, standard multigrid cycles are used, such as V-Cycle, F-Cycle, etc. The GMRES algorithm discusses the algorithm iteration principle and uses the incomplete LU decomposition method to preprocess the matrix of the equation system, so that the ill-conditioned matrix can be improved. The actual oil well numerical simulation shows that compared with the traditional Gauss-Seidel iteration method, the generalized minimum residual algorithm has great superiority in operation speed, and the matrix preprocessing increases the operation speed by at least 1 times.

[0037] Figure 1 It is an optional flow chart of a method for evaluating the volume of sand bodies controlled by horizontal wells based on geological and engineering integration provided in an embodiment of the present application, which may include but is not limited to steps S1 to S5.

[0038] Step S1, based on geological engineering data, reservoir configuration unit division and boundary identification are performed to construct a three-dimensional configuration distribution model and a sand-mud model.

[0039] Specifically, geological engineering data includes basic geological data and fracturing construction data. Basic geological data includes geological stratification data, well logging data, sand and mud interpretation data, etc. Fracturing construction data is relevant data in the actual fracturing process, such as perforation data, sand addition amount, liquid addition amount, displacement, etc.

[0040] Furthermore, the technical route of step S1 is as follows Figure 2 As shown, it may include but is not limited to steps S11 to S20.

[0041] Step S11, according to the sedimentary facies type and the architectural elements, a well logging identification plate for the architectural unit is established, and each well in the study area is divided into architectural units.

[0042] Specifically, the identification of configuration units involves the following steps: ① Geological survey and data collection: Collect basic data such as geological exploration reports, well logging data, seismic interpretation results, and conduct geological outcrop observations, core observations and analysis to obtain detailed petrological information and sedimentary structural characteristics, and understand the macroscopic characteristics and sedimentary environment of the reservoir.

[0043] ② Identification of structural units: According to the color, composition, grain size, sedimentary structure and other characteristics of the sediments, the sedimentary facies type is identified to understand the evolution of the sedimentary environment; the structural elements such as river channels, mid-bars and point-bars are identified using well logging data and seismic interpretation results, and a structural unit logging identification chart is established to divide each well in the study area into structural units.

[0044] Step S12: establishing a correlation equation between the length and width of each configuration unit based on the length and width distribution range of each configuration unit.

[0045] Step S13, predicting the plane distribution range of the sand body by combining well and seismic data, based on the scale characteristics of the configuration units obtained by single well configuration analysis and field outcrop observation, and guided by the sedimentary model, characterizing the plane distribution characteristics of each configuration unit in the study area.

[0046] Step S14, identifying and dividing the configuration units of each well in the study area, and clarifying the dominant configuration units developed in each layer; Step S15, characterizing the range of the sand body based on the well-seismic data, identifying and characterizing the distribution scale and shape of the river channel within the sand body boundary; Step S16, defining the top and bottom interfaces of each river channel as two key levels to form a river channel configuration unit; Step S17, by identifying and depicting the top and bottom interfaces of the mid-shoal, a distribution model of the mid-shoal configuration unit is constructed inside the channel configuration unit.

[0047] Step S18, analyzing the core data of the coring well, and establishing a corresponding chart of sandstone and mudstone and the well logging curve; Specifically, the steps rely on a detailed description and analysis of the core samples, including the composition, structure, grain size distribution and sedimentary characteristics of the rock.

[0048] Step S19, using the sand-mud discrimination template, analyzing the single well logging data to identify and classify sandstone and mudstone; Specifically, the steps generally involve interpretation of well logging curves and verification with core data to ensure the accuracy of the division between sandstone and mudstone.

[0049] Step S20, under the constraint of the three-dimensional configuration distribution model, a three-dimensional sand and mud model is established based on the spatial relationship between wells and geological trends by using a sequential indicator simulation method.

[0050] Step S2, based on the fracturing construction data, using the unconventional fracture network model UFM, simulates the fractures to obtain fracture length and fracture height parameters of the fractures; Further, the technical route of step S2 is as follows Figure 3 As shown, it may include but is not limited to steps S21 to S22.

[0051] Step S21, fitting the field perforation data and the fracturing pumping program; Specifically, in order to make the fracture simulation more consistent with the actual situation of the mine, the field perforation data (perforation location and size) and the fracturing pumping program (total liquid volume, pre-fluid, sand-carrying fluid, proppant and displacement fluid, etc.) are fitted before the simulation.

[0052] Step S22: Based on the geological model, an unconventional fracture network model UFM is used for simulation to obtain fracture length and fracture height parameters of the hydraulic fracture.

[0053] Specifically, based on the geological model, the unconventional fracture network model (UFM) is adopted to fully consider factors such as reservoir heterogeneity, stress anisotropy, one-dimensional flow of fracturing fluid, transport of proppant and elastic deformation of fracture width, and to consider the interaction of stresses between adjacent fractures by calculating stress shadows. The fractures are accurately simulated and finally the parameters such as fracture length and fracture height of the fracture are obtained.

[0054] Step S3, based on the production dynamic data of the study area, simulate the production dynamic value, and obtain the horizontal well control area based on the historical fitting and future production prediction of each well; Further, the technical route of step S3 is as follows Figure 4 As shown, it may include but is not limited to steps S31 to S33.

[0055] Step S31, collecting and collating the production dynamic data of the study area and coarsening the grid of the geological model; Specifically, before numerical simulation, it is necessary to collect and organize the production dynamic data of the study area, including but not limited to gas production, water production, pressure, phase permeability curve, and fluid PVT data. However, when the wellbore is throttled downhole and there is a liquid accumulation problem in the study area, the bottom hole flow pressure has high uncertainty. The Beggs-Brill multiphase flow model can be used to accurately calculate the bottom hole flow pressure, which is consistent with the downhole flow pressure test results.

[0056] Furthermore, the grid of the geological model is generally finer than that of the reservoir numerical model, so the geological model needs to go through a grid coarsening process before entering the numerical simulator. The purpose of model coarsening is to increase the computing speed of reservoir numerical simulation by reducing the number of grids, thereby reducing time costs. In order to maintain the information equivalence before and after the model coarsening as much as possible, the NTG weighted average is used for the porosity model; considering the fluid flow characteristics, there are many coarsening methods available for the permeability model; the gas saturation model uses volume weighted arithmetic mean, and porosity and NTG are used for weighting; the NTG model uses volume weighted arithmetic mean.

[0057] Step S32, starting the pressure gradient and stress sensitivity settings, setting the threshold pressure between two grid blocks to equivalently start the pressure gradient, and using the rock compression and expansion permeability multiplier table to characterize the stress sensitivity; Specifically, due to the adsorption of fluid on the rock surface in the tight low-permeability reservoir, additional resistance is generated; the surface of clay minerals adsorbs water to form a water film, which generates additional resistance; when the fluid wants to flow under the action of external force, there is static friction between the capillary wall. Therefore, in the simulation, the threshold pressure between the two grid blocks needs to be set to equivalently start the pressure gradient. For example, if the starting pressure gradient value is 0.02 MPa / m and the grid size in the numerical simulation is 50 m, then 0.02×50=1MPa is set as the threshold pressure between the two grid blocks. When the threshold pressure is less than the flow pressure between the two grids, the fluid starts to flow; otherwise, the fluid will not flow.

[0058] Furthermore, during the oil and gas development process, as the fluid in the reservoir is continuously produced, the formation pore pressure decreases, and the effective stress on the reservoir rock skeleton continues to increase, causing the reservoir seepage channel to close and the permeability to decrease, thus forming stress sensitive damage. Therefore, the rock compression and expansion permeability multiplier table (ROCKTAB table) is used in software simulation to characterize stress sensitivity.

[0059] Step S33, using the enumeration balance method to initialize the model and simulate the gas reservoir values ​​in the study area.

[0060] Specifically, the initialization of the gas reservoir numerical simulation model is an important part of the oil reservoir numerical simulation calculation. The high-precision model initialization process is a necessary guarantee for obtaining reliable results of gas reservoir numerical simulation. The enumeration balance method is used to initialize the model. The process of calculating the reservoir pressure field is consistent with the equilibrium initialization reservoir pressure field calculation process, but the fluid saturation field is no longer calculated based on the endpoint value of the phase permeability curve. Instead, it is enumerated by the saturation output by the three-dimensional geological model; then, the phase permeability curve endpoint is calibrated to generate a new phase permeability curve; through the capillary pressure calibration, the balance of the fluid saturation field in the initial state is guaranteed, which can improve the accuracy of the numerical model and make the numerical simulation model more in line with the actual mine field.

[0061] Step S4, based on fracture simulation and production dynamic numerical simulation, obtain the three-dimensional volume controlled by the horizontal well.

[0062] Specifically, the numerical simulation of the gas reservoir in the study area was carried out based on Petrel RE, and the pressure residual constraint CPR algorithm was applied to decouple the pressure and saturation equations. The pressure equation was solved by the algebraic multigrid AMG algorithm, and the saturation equation was solved by the GMRES algorithm with incomplete LU decomposition preprocessing, which accelerated the simulation calculation by more than 3 times. On this basis, the production data was fitted. Based on the actual production data of the oil field, the simulation step length was 1 month, and the production mode adopted fixed gas production.

[0063] Furthermore, based on the dynamic numerical simulation of production in the study area and the historical fitting of each well, the accurate production situation of each well and the control area during the production process are obtained. In order to obtain the final control area, it is necessary to predict the future production of each well based on the original production information to obtain the final horizontal well control area.

[0064] Furthermore, based on the three-dimensional sand-mud model, fracture simulation and numerical simulation, the vertical range of the sand body controllable by the horizontal well is obtained based on the fracture simulation, and the planar range controllable by the horizontal well is obtained based on the numerical simulation. The combination of the two can obtain the three-dimensional volume controlled by the horizontal well.

[0065] Step S5, obtaining the volume of sand body controlled by the horizontal well by subtracting the mud volume obtained by the sand-mud model from the three-dimensional volume controlled by the horizontal well.

[0066] Specifically, the three-dimensional volume controlled by the horizontal well contains not only sand but also mud. Therefore, in the sand-mud model, the mud within this range is filtered out, its volume is calculated, and then the volume of the mud is subtracted from the total volume to obtain the volume of the sand body controlled by the horizontal well.

[0067] The following describes a process of one embodiment of the present invention, including the following: Step ①, based on the acquisition of geological engineering data, the basic geological data and fracturing construction data of the gas field were collected and organized. Based on the configuration analysis and model establishment, the configuration units of the gas field were divided. It mainly includes three types: braided channel, shoal and floodplain. The corresponding configuration unit logging identification plate was established, and the configuration unit was divided for each well in the study area. In addition, through field outcrop investigation and actual measurement, the scale of the braided channel and shoal was obtained, and the correlation between the length and width of the shoal was established: the correlation function is Y=0.43X+17.501 (R 2 =0.90), where Y represents the width of the mid-bar and X represents the length of the mid-bar; and the correlation between the width of the braided channel and the width of the mid-bar: the correlation function is Y=6.74X+9.98 (R 2 =0.73), where Y represents the width of the center bar and X represents the width of the braided channel. Then, the planar distribution range of the sand body was characterized by the sand and mud data on the well and the seismic data. Then, under the guidance of the sedimentary model, based on the configuration analysis of each well and the scale characteristics of the configuration unit obtained by field outcrop observation, the planar distribution characteristics of each configuration unit of the gas field were characterized. On this basis, the "hierarchical constraint and interface control" method was used to construct a three-dimensional configuration distribution model (such as Figure 5 Then, under the constraints of the model, a three-dimensional sand and mud distribution model was established by using sequential indicator simulation.

[0068] Step ②, based on the fracturing simulation, the perforation parameters and pump main program of the actual mine were fitted, and on the basis of the geological model, the UFM fracture simulation method was used to obtain the fracture length and fracture height parameters of the horizontal well (such as Figure 6 as shown).

[0069] Step ③, based on the production dynamic numerical simulation, the production dynamic data such as gas production, water production, pressure, phase permeability curve and fluid PVT of the study area are collected and sorted, and the Beggs-Brill multiphase flow model is used to realize the accurate calculation of the bottom hole flow pressure; in order to improve the running speed of the numerical simulation, the original geological model is coarsened and the number of multi-grids is reduced by half. In order to accurately characterize the characteristics of the dense low-permeability reservoir, the starting pressure gradient and stress sensitivity setting method are adopted. Then the enumeration balance method is used to initialize the model to improve the accuracy of the numerical model and make the numerical simulation model more in line with the actual mine. Finally, through the production dynamic simulation, the production data is fitted to obtain the accurate production situation of each well and the control area during the production process. In order to obtain the final control area, the production of each well is predicted for the next 15 years based on the original production information to obtain the final horizontal well control area (such as Figure 7 as shown).

[0070] Step ④, based on the method for obtaining the volume of sand bodies controlled by horizontal wells, the vertical range of the sand bodies controlled by horizontal wells obtained by fracture simulation and the plane range of the sand bodies controlled by horizontal wells obtained by numerical simulation are combined to obtain the three-dimensional volume controlled by the horizontal wells, and the mud within this range is filtered out to calculate its volume, and then the volume of the mud is subtracted from the total volume to finally obtain the volume of the sand bodies controlled by the horizontal wells (such as Figure 8 shown) The device embodiments described above are merely illustrative, wherein the units described as separate components may or may not be physically separated, and the components displayed as units may or may not be physical units, that is, they may be located in one place, or they may be distributed on multiple network units. Some or all of the modules may be selected according to actual needs to achieve the purpose of the scheme of this embodiment. Ordinary technicians in this field can understand and implement it without paying creative labor.

[0071] Through the description of the above implementation methods, those skilled in the art can clearly understand that each implementation method can be implemented by means of software plus a necessary general hardware platform, and of course, can also be implemented by hardware. Based on this understanding, the above technical solution is essentially or the part that contributes to the prior art can be embodied in the form of a software product, and the computer software product can be stored in a computer-readable storage medium, such as ROM / RAM, a disk, an optical disk, etc., including a number of instructions for a computer device (which can be a personal computer, a server, or a network device, etc.) to execute the methods described in each embodiment or some parts of the embodiments.

[0072] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit it. Although the present invention has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or make equivalent replacements for some of the technical features therein. However, these modifications or replacements do not deviate the essence of the corresponding technical solutions from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A method for evaluating the volume of sand bodies controlled by horizontal wells, characterized in that: include: Step S1, based on geological engineering data, reservoir configuration unit division and boundary identification are performed to construct a three-dimensional configuration distribution model and a sand-mud model; Step S2, based on the fracturing construction data, using the unconventional fracture network model UFM, simulates the fractures to obtain fracture length and fracture height parameters of the fractures; Step S3, based on the production dynamic data of the study area, a production dynamic numerical simulation is performed, and based on the historical matching and future production prediction of each well, the horizontal well control area is obtained; Step S4, obtaining a three-dimensional volume controlled by the horizontal well based on fracture simulation and production performance numerical simulation; Step S5, obtaining the volume of sand body controlled by the horizontal well by subtracting the mud volume obtained by the sand-mud model from the three-dimensional volume controlled by the horizontal well.

2. The method for evaluating the volume of sand bodies controlled by horizontal wells according to claim 1, characterized in that: The geological engineering data include basic geological data, and the basic geological data include geological stratification data, well logging data and / or sand and mud interpretation data.

3. The method for evaluating the volume of sand bodies controlled by horizontal wells according to claim 1, characterized in that: The geological engineering data also includes fracturing construction data, and the fracturing construction data includes perforation data, sand addition amount, liquid addition amount and / or displacement.

4. The method for evaluating the volume of sand bodies controlled by horizontal wells according to claim 1, characterized in that: The step 1 further comprises: Step S11, establishing a well logging identification plate for configuration units according to the sedimentary facies type and configuration elements, and dividing each well in the study area into configuration units; Step S12, establishing a correlation equation between the length and width of each configuration unit based on the length and width distribution range of each configuration unit; Step S13, predicting the plane distribution range of the sand body by combining well and seismic data, based on the scale characteristics of the configuration units obtained by single well configuration analysis and field outcrop observation, and guided by the sedimentary model, characterizing the plane distribution characteristics of each configuration unit in the study area.

5. The method for evaluating the volume of sand bodies controlled by horizontal wells according to claim 3, characterized in that: The step 1 further comprises: Step S14, identifying and dividing the configuration units of each well in the study area, and clarifying the dominant configuration units developed in each layer; Step S15, characterizing the range of the sand body based on the well-seismic data, identifying and characterizing the distribution scale and shape of the river channel within the sand body boundary; Step S16, defining the top and bottom interfaces of each river channel as two key levels to form a river channel configuration unit; Step S17, by identifying and depicting the top and bottom interfaces of the mid-shoal, a distribution model of the mid-shoal configuration unit is constructed inside the channel configuration unit.

6. The method for evaluating the volume of sand bodies controlled by horizontal wells according to claim 4, characterized in that: The step 1 further comprises: Step S18, analyzing the core data of the coring well, and establishing a corresponding chart of sandstone and mudstone and the well logging curve; Step S19, using the sand-mud discrimination template, analyzing the single well logging data to identify and classify sandstone and mudstone; Step S20, under the constraint of the three-dimensional configuration distribution model, a three-dimensional sand and mud model is established based on the spatial relationship between wells and geological trends by using a sequential indicator simulation method.

7. The method for evaluating the volume of sand bodies controlled by horizontal wells according to claim 1, characterized in that: The step 2 further comprises: Step S21, fitting the field perforation data and the fracturing pumping program; Step S22: Based on the geological model, an unconventional fracture network model UFM is used for simulation to obtain fracture length and fracture height parameters of the hydraulic fracture.

8. The method for evaluating the volume of sand bodies controlled by horizontal wells according to claim 1, characterized in that: The step 3 further comprises: Step S31, collecting and collating the production dynamic data of the study area and coarsening the grid of the geological model; Step S32, starting the pressure gradient and stress sensitivity settings, setting the threshold pressure between two grid blocks to equivalently start the pressure gradient, and using the rock compression and expansion permeability multiplier table to characterize the stress sensitivity; Step S33, using the enumeration balance method to initialize the model and simulate the gas reservoir values ​​in the study area.

9. The method for evaluating the volume of sand bodies controlled by horizontal wells according to claim 1, characterized in that: The step 3 further comprises: Based on the fracture simulation, the vertical range of the sand body that can be controlled by the horizontal well is obtained, and based on the numerical simulation, the planar range that can be controlled by the horizontal well is obtained.

10. The method for evaluating the volume of sand bodies controlled by horizontal wells according to claim 1, characterized in that: The step 4 further comprises: The vertical range of the sand body controlled by the horizontal well obtained based on the fracture simulation and the plane range of the sand body controlled by the horizontal well obtained based on the numerical simulation are combined to obtain the three-dimensional volume controlled by the horizontal well.

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