Comprehensive evaluation method and device for fracture network sweep efficiency of shale oil horizontal well volume fracturing

Abstract

The application discloses a shale oil horizontal well volume fracturing fracture network sweep efficiency comprehensive evaluation method and device, the method comprises the following steps: obtaining shale oil horizontal well volume fracturing mine field data, and obtaining effective fracture network reconstruction volume according to the mine field data; obtaining shale oil horizontal well core data, and obtaining imbibition sweep volume according to the core data; obtaining fracture network sweep efficiency according to effective fracture network reconstruction volume, imbibition sweep volume and shale oil horizontal well volume fracturing mine field data. The application can quantitatively calculate the effective fracture network reconstruction volume of the horizontal well volume fracturing proppant, compared with the current mainstream microseismic monitoring means, the method of the application greatly saves the test cost, the calculation method is simple and feasible, the accuracy is greatly improved, and the volume fracturing reconstruction effect evaluation is effectively supported.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of oil and gas engineering, in particular to a shale oil horizontal well volumetric fracturing fracture network sweep efficiency comprehensive evaluation method and device. BACKGROUND

[0002] China is rich in shale oil resources, and the technically recoverable resource volume is 145 x 10 8 t, becoming the most strategic oil replacement resource and the main force for increasing reserves and production of crude oil in China. Horizontal well segmented multi-cluster volumetric fracturing is a key technology for efficient development of shale oil and gas, and fracture network sweep efficiency is a core index for development effect evaluation. The larger the value, the better the fracturing effect. It plays a key role in the optimization and improvement of volumetric fracturing technology. At present, how to quantitatively characterize is a major challenge in unconventional reservoir reconstruction, such as the effective proppant support length in the fracture, the imbibition volume of fracturing in the pore, etc.

[0003] Fracture network sweep efficiency is the ratio of fracture network swept volume to horizontal well control volume. Among them, the fracture network swept volume of unconventional shale oil includes the effective fracture network reconstruction volume formed by volumetric fracturing and the imbibition swept volume of multi-scale micro-nano pores. Some studies have effectively analyzed the fracture network swept volume and sweep efficiency, for example, Jiao Fangzheng's 2021 study on fracture network sweep of shale oil in Ordos Basin and its application in volumetric development published in Oil and Gas Geology. A subdivision cutting volumetric fracturing fracture network swept volume calculation model is proposed. The method of multiple linear regression is used to establish the relationship between key geological engineering parameters and microseismic coverage volume. Further, the relationship is corrected using actual production data from the mine site, and an empirical formula for quantitatively characterizing the fracture network swept volume is established. Furthermore, a correlation chart between fracture network swept volume and productivity is drawn, providing guidance for the optimization of volumetric fracturing engineering parameters.

[0004] Patent CN110738001A discloses a method for calculating the fracturing stimulation area of unconventional reservoirs. By establishing a two-dimensional reconstruction volume calculation equivalent mathematical model, combining the initial and internal and external boundary conditions of the mathematical model, and iteratively coupling the fluid mass conservation equation and the fracture width equation in the fracture system, the fracture fluid pressure and average fracture width in each grid block are obtained, thereby obtaining the fracture reconstruction volume size. This method quantitatively calculates the fracture volume size by establishing a mathematical model, but the unconventional reservoir has strong heterogeneity, and the multi-fracture propagation law is still a difficult problem in the field, making fracture volume prediction more difficult. This method is a numerical simulation method with many assumptions, and the prediction result has a large difference from the true value.

[0005] The patent CN109507723A discloses a method and system for calculating the fracturing volume of a microseismic fracturing fracture model, and the microseismic fracturing fracture model is equivalent to a triangular face polyhedral model; the triangular face in the triangular face polyhedral model is projected to obtain the fracturing volume of the microseismic fracturing fracture model. The microseismic monitoring event point is related to the mechanical properties of the rock and the monitoring accuracy of the equipment, and a large number of practices prove that the microseismic monitoring range is much larger than the hydraulic fracture range, and thus the method calculates the fracture volume to be larger.

[0006] In summary, the current main methods for obtaining the fracture volume mainly include reservoir numerical simulation and microseismic monitoring technology, and the microseismic monitoring technology is a commonly used method in large oilfields. However, unconventional reservoirs usually adopt multi-stage and multi-cluster fracturing, and it is impossible to use the microseismic monitoring technology for each stage, the test cycle is long, the test cost is high, and it is difficult to test and apply to the whole well section in the oilfield, and at the same time, the effective proppant volume of the horizontal well volume fracturing in the fracture cannot be obtained, and the imbibition volume under the action of reservoir fluid and capillary pressure of unconventional reservoirs cannot be quantitatively characterized. Therefore, it is necessary to propose a new shale oil horizontal well volume fracturing fracture network sweep coefficient comprehensive evaluation method which can represent the effective proppant volume and the imbibition volume, and provide important theoretical support for the efficient development of unconventional resources. SUMMARY

[0007] In order to solve the problems existing in the prior art, the present application provides a shale oil horizontal well volume fracturing fracture network sweep coefficient comprehensive evaluation method, which comprises,

[0008] Obtaining data information of a shale oil horizontal well volume fracturing mine field, and obtaining an effective fracture network reconstruction volume according to the data information of the mine field;

[0009] Obtaining data information of a shale oil horizontal well core, and obtaining an imbibition sweep volume according to the data information of the core;

[0010] Obtaining a fracture network sweep coefficient according to the effective fracture network reconstruction volume, the imbibition sweep volume and the data information of the shale oil horizontal well volume fracturing mine field.

[0011] Further, the obtaining of the data information of the shale oil horizontal well volume fracturing mine field and the obtaining of the effective fracture network reconstruction volume according to the data information of the mine field comprises,

[0012] Obtaining reservoir physical parameters, basic parameters of the shale oil horizontal well, microseismic monitoring parameters of the shale oil horizontal well volume fracturing and historical parameters of the horizontal well production dynamics of the shale oil horizontal well volume fracturing mine field, and constructing a shale oil horizontal well basic database;

[0013] According to the shale oil horizontal well basic database, a shale oil horizontal well productivity prediction model is established, and a fracture network volume is corrected by using a reservoir numerical simulation production history matching method to obtain an effective fracture network reconstruction volume V ESRV .

[0014] Further, the reservoir physical property parameters of the shale oil horizontal well volume fracturing field include reservoir burial depth, effective thickness, original formation pressure, reservoir temperature, formation fluid parameter, average porosity, average permeability, and average oil saturation.

[0015] The shale oil horizontal well basic parameters include a horizontal section length, a fracturing section number, and a total fracturing fluid volume.

[0016] The shale oil horizontal well volume fracturing microseismic monitoring parameters include a shale oil horizontal well microseismic monitoring corresponding fracture network volume SRV of each fracturing section.

[0017] The horizontal well production dynamic history parameters include an actual cumulative oil production within a certain time.

[0018] Further, the data of the shale oil horizontal well core is obtained, and the imbibition sweep volume is obtained according to the data of the core.

[0019] The porosity of a standard rock sample made of the core drilled downhole by the shale oil horizontal well or the shale oil horizontal well of the same layer in the same block is obtained.

[0020] The total fracture imbibition area of the shale oil horizontal well is obtained according to the imbibition experimental data of the standard rock sample.

[0021] The imbibition sweep volume is obtained according to the total fracture imbibition area of the shale oil horizontal well, the porosity of the standard rock sample, and the imbibition sweep volume.

[0022] Further, the imbibition sweep volume is obtained according to the total fracture imbibition area of the shale oil horizontal well, the porosity of the standard rock sample, and the imbibition sweep volume, which is calculated by the following formula.

[0023]

[0024] In the formula, V imb is the imbibition sweep volume; is the porosity of the standard rock sample; σ is the surface tension; θ is the wet contact angle; r is the rock pore radius; A is the fracture area; μ is the imbibition liquid viscosity; and t is the imbibition time.

[0025] Further, the shale oil horizontal well basic parameters further include,

[0026] The oil layer thickness of the shale oil horizontal well, the horizontal well spacing, and the oil layer drilling rate.

[0027] Further, the fracture network sweep efficiency is calculated according to the effective fracture network reconstruction volume, the imbibition sweep volume and the data of the shale oil horizontal well volume fracturing field by the following formula,

[0028]

[0029] In the formula, E f is the fracture network sweep efficiency, dimensionless; L is the length of the horizontal section of the shale oil horizontal well; h is the oil layer thickness; d is the well spacing of the shale oil horizontal well; s is the oil layer drilling rate; V ESRV is the effective fracture network reconstruction volume; V imb is the imbibition sweep volume.

[0030] The application also provides a shale oil horizontal well volume fracturing fracture network sweep efficiency comprehensive evaluation device, which comprises,

[0031] A first data unit is used to acquire the data of the shale oil horizontal well volume fracturing field and acquire the effective fracture network reconstruction volume according to the data of the field;

[0032] A second data unit is used to acquire the data of the shale oil horizontal well core and acquire the imbibition sweep volume according to the data of the core;

[0033] A sweep efficiency unit is used to acquire the fracture network sweep efficiency according to the effective fracture network reconstruction volume, the imbibition sweep volume and the data of the shale oil horizontal well volume fracturing field.

[0034] Further, the first data unit further comprises,

[0035] A parameter acquisition module is used to acquire the reservoir physical property parameters of the shale oil horizontal well volume fracturing field, the basic parameters of the shale oil horizontal well, the shale oil horizontal well volume fracturing microseismic monitoring parameters and the horizontal well production dynamic history parameters, and construct a shale oil horizontal well basic database;

[0036] A reconstruction volume module is used to establish a productivity prediction model of the shale oil horizontal well according to the shale oil horizontal well basic database, correct the fracture network volume by using the reservoir numerical simulation production history matching method, and acquire the effective fracture network reconstruction volume V ESRV .

[0037] Further, the second data unit further comprises,

[0038] A porosity module is used to acquire the porosity of the standard rock sample made of the core drilled downhole by the shale oil horizontal well or the shale oil horizontal well in the same block and the same layer;

[0039] A total area module is used to acquire the total fracture imbibition area of the shale oil horizontal well according to the imbibition experimental data of the standard rock sample.

[0040] The swept volume module is used for obtaining the percolation swept volume according to the total fracture percolation area of the shale oil horizontal well, the porosity of the standard rock sample and the percolation swept volume.

[0041] Compared with the prior art, the present application has the following beneficial effects:

[0042] (1) The present application proposes a new comprehensive evaluation method for the fracture network swept coefficient of the shale oil horizontal well volume fracturing, which simultaneously solves the problems of quantitative characterization of the effective volume and percolation swept volume of the current unconventional horizontal well volume fracturing reconstruction.

[0043] (2) The present application can quantitatively calculate the effective fracture network reconstruction volume of the horizontal well volume fracturing proppant, compared with the current mainstream microseismic monitoring method, the method of the present application greatly saves the test cost, the calculation method is simple and feasible, and the accuracy is greatly improved, which effectively supports the evaluation of the volume fracturing reconstruction effect.

[0044] (3) The present application realizes the quantitative characterization of the percolation swept volume after the volume fracturing of the unconventional multi-scale micro-nano pore, solves the limitation of the previous single experimental method, and is applied to the field scale, and the evaluation method is greatly improved.

[0045] Other features and advantages of the present application will be set forth in the specification, and in part will become apparent from the specification, or can be learned by practice of the present application. The objects and other advantages of the present application can be realized and obtained by the steps or devices indicated in the specification and drawings. BRIEF DESCRIPTION OF DRAWINGS

[0046] In order to more clearly illustrate the technical solutions in the embodiments of the present application or the prior art, the following will briefly introduce the drawings needed to be used in the embodiment or prior art description. Obviously, the drawings in the following description are some embodiments of the present application, and for those skilled in the art, other drawings can also be obtained without creative labor on the basis of these drawings.

[0047] Figure 1 The flow chart of the comprehensive evaluation method for the fracture network swept coefficient of the shale oil horizontal well volume fracturing of the present application is shown;

[0048] Figure 2 The fracture network volume of the microseismic monitoring in the embodiment of the present application is shown;

[0049] Figure 3 The double logarithmic curve of the percolation amount per unit area and the percolation time in the embodiment of the present application is shown;

[0050] Figure 4 A schematic diagram of a comprehensive evaluation device for fracture network sweep efficiency of volume fracturing of a horizontal well in an embodiment of the present application is shown. DETAILED DESCRIPTION

[0051] The inventive concept of the present application is that, first, based on microseismic monitoring data of a volume fracturing of a horizontal well in a field, a full-well-section fracture network volume is obtained, and the fracture network volume is corrected using a reservoir numerical simulation production history matching method to obtain an effective fracture network reconstruction volume. Second, based on a rock microstructure and wettability, a multi-scale pore imbibition model is established to calculate an imbibition sweep volume. Finally, based on the effective fracture network reconstruction volume, the imbibition sweep volume, and reservoir parameters of the horizontal well, a fracture network sweep efficiency is quantitatively calculated, so as to achieve the purpose of comprehensive evaluation of the fracture network sweep efficiency of volume fracturing of a horizontal well in shale oil.

[0052] The technical solutions in the embodiments of the present application will be clearly and completely described below with reference to specific embodiments of the present application and the accompanying drawings. Obviously, the described embodiments are only some of the embodiments of the present application, but not all the embodiments. Based on the embodiments in the present application, all other embodiments obtained by those skilled in the art without creative work fall within the scope of protection of the present application. In the embodiments, each raw reagent material can be commercially available, and the experimental method without specific conditions is a conventional method and conventional condition known in the art, or a condition recommended by the manufacturer of the instrument.

[0053] As shown in Figure 1 An embodiment of the present application provides a comprehensive evaluation method for fracture network sweep efficiency of volume fracturing of a horizontal well in shale oil, comprising the following steps,

[0054] S101, obtaining data information of a volume fracturing field of a horizontal well in shale oil, and obtaining an effective fracture network reconstruction volume according to the data information of the field.

[0055] Preferably, step S101 comprises,

[0056] S1011, obtaining reservoir physical property parameters of a volume fracturing field of a horizontal well in shale oil, basic parameters of the horizontal well, microseismic monitoring parameters of volume fracturing of the horizontal well, and historical parameters of production dynamics of the horizontal well, and constructing a basic database of the horizontal well in shale oil.

[0057] The basic database is established by using an analytic hierarchy process to establish a multi-level evaluation system, which includes four parts of reservoir physical property parameters of a volume fracturing field of a horizontal well in shale oil, basic parameters of the horizontal well, microseismic monitoring parameters of volume fracturing of the horizontal well, and historical parameters of production dynamics of the horizontal well.

[0058] Preferably, the reservoir physical property parameters of the shale oil horizontal well volume fracturing minefield include reservoir burial depth, effective thickness, original formation pressure, reservoir temperature, formation fluid parameters, average porosity, average permeability, and average oil saturation.

[0059] The shale oil horizontal well basic parameters include horizontal section length, fracturing section number, and total fracturing fluid volume.

[0060] The shale oil horizontal well volume fracturing microseismic monitoring parameters include the microseismic monitoring corresponding fracture network volume SRV of each fracturing section of the shale oil horizontal well.

[0061] The horizontal well production dynamic history parameters include actual cumulative oil production within a certain time, which can be a research cycle time, for example, 1 year.

[0062] S1012, according to the shale oil horizontal well basic database, a shale oil horizontal well productivity prediction model is established, and the fracture network volume is corrected by using the reservoir numerical simulation production history matching method to obtain the effective fracture network reconstruction volume V ESRV .

[0063] According to the shale oil horizontal well basic database, a geological model is established by using a reservoir numerical simulation software, the geological model includes a reservoir porosity distribution field, a permeability distribution field, an oil saturation distribution field, and a formation pressure distribution field, etc. SRV The shale oil horizontal well productivity prediction model is obtained by importing the geological model.

[0064] The reservoir numerical simulation production history matching correction is calculated according to the following formula,

[0065]

[0066] In the formula, V ESRV is the effective fracture network reconstruction volume, 10 4 m 3 ; Q h is the cumulative oil production of the shale oil horizontal well at a certain time, tons; Q p is the cumulative oil production of the shale oil horizontal well at a certain time, tons; SRV is the fracture network volume, 10 4 m 3 ; i is the fracturing section number; n is the fracturing section number, section.

[0067] S102, the data of the shale oil horizontal well core is obtained, and the imbibition wave volume is obtained according to the data of the core.

[0068] S1021, Obtain the porosity of the standard rock sample made of the core drilled by the shale oil horizontal well in the reservoir or the same layer shale oil horizontal well in the same block.

[0069] In the shale oil horizontal well reservoir or the same layer shale oil horizontal well in the same block, the core is drilled and a standard rock sample with a diameter of 2.5 cm and a length of 5 cm is made. The standard rock sample is placed in a 100℃ oven and dried to constant weight;

[0070] The porosity of the dried standard rock sample is tested by using a porosity tester with helium as the working medium.

[0071] S1022, Obtain the total fracture imbibition area of the shale oil horizontal well according to the imbibition experimental data of the standard rock sample.

[0072] In the imbibition experiment, the imbibition amount changes with the imbibition time, and the imbibition model of the imbibition amount and time is established. According to the experimental data, the double logarithmic curve of the imbibition amount per unit area and the imbibition time is drawn, and the curve is fitted with a linear function, and the linear function expression is as follows,

[0073]

[0074] In the formula: V is the imbibition volume, m 3 ; A is the fracture area, m 2 ; t is the imbibition time, min; B and C are coefficients, dimensionless.

[0075] The relationship between the volume fracturing imbibition amount, fracture imbibition area and imbibition time of the shale oil horizontal well is obtained as follows,

[0076]

[0077] In the formula: V n is the imbibition volume of the nth section of the horizontal well volume fracturing, m 3 ; A f is the fracture imbibition area of each fracturing section, m 2 ; t n is the imbibition time of the nth section of the reservoir, min.

[0078] According to the sum of the imbibition volumes of each fracturing section being equal to the total fracturing fluid volume and the imbibition time of each fracturing section being the same after volume fracturing, the total fracture imbibition area of the shale oil horizontal well is obtained,

[0079] V1+V1+…V n =V

[0080] t1=t2=t n =t

[0081]

[0082] In the formula, A is the total area of fracture imbibition of the shale oil horizontal well.

[0083] S1023, obtaining the imbibition swept volume according to the total area of fracture imbibition of the shale oil horizontal well and the porosity of the standard rock sample.

[0084] The imbibition swept volume calculation basic parameters include porosity, surface tension, wet contact angle, rock pore radius, imbibition liquid viscosity and imbibition time, which can be directly obtained in the imbibition experiment.

[0085] The formula is calculated as follows,

[0086]

[0087] In the formula, V imb is the imbibition swept volume, cm 3 ; is the porosity, %; σ is the surface tension, mN / m; is the wet contact angle, °; r is the rock pore radius, cm. A is the fracture area, cm 2 ; μ is the imbibition liquid viscosity, mPa·s; t is the imbibition time, min.

[0088] S103, obtaining the fracture network swept coefficient according to the effective fracture network reconstruction volume, the imbibition swept volume and the data of the shale oil horizontal well volume fracturing field.

[0089] Specifically, the following formula is calculated:

[0090]

[0091] In the formula, E f is the fracture network swept coefficient, dimensionless; L is the horizontal section length of the shale oil horizontal well; h is the oil layer thickness; d is the shale oil horizontal well spacing; s is the oil layer drilling rate; V ESRV is the effective fracture network reconstruction volume; V imb is the imbibition swept volume.

[0092] The larger the fracture network swept coefficient is, the better the volume fracturing effect of the shale oil reservoir horizontal well is.

[0093] One embodiment of the present application applies the above method embodiment to the fracture network swept coefficient comprehensive evaluation of the volume fracturing reconstruction of a shale oil reservoir horizontal well. The number of the shale oil horizontal well to be evaluated is QH1-1, the horizontal section length is 1700m, the oil layer drilling rate is 79.5%, and a total of 18 sections are fractured, of which 18 sections are monitored by microseismic. The related calculation formula is not repeated and please refer to the method embodiment, and the specific process is as follows:

[0094] 1. Based on the microseismic monitoring data of the volume fracturing of the horizontal well, the fracture network volume of the whole well section is obtained, and the fracture network volume is corrected by using the production history matching method of reservoir numerical simulation to obtain the effective fracture network reconstruction volume, which specifically includes the following contents:

[0095] (1) Establishment of shale oil horizontal well basic database: a multi-level evaluation system is established by using the analytic hierarchy process, which includes four parts of shale oil reservoir parameters, shale oil horizontal well basic parameters, shale oil horizontal well volume fracturing microseismic monitoring parameters and shale oil horizontal well production dynamic history parameters, and the specific contents are as follows:

[0096] ① The shale oil reservoir physical property parameters of QH1-1 well are obtained as shown in Table 1.

[0097] Table 1 Shale oil reservoir physical property parameters of QH1-1 well

[0098]

[0099] ② The horizontal section length of QH1-1 well is 1700m, the number of fracturing sections is 18, and the total fracturing fluid volume is 27385m 3 .

[0100] ③ The fracture network volume SRV of each fracturing section of QH1-1 well volume fracturing microseismic monitoring is as shown in the following table. Figure 2

[0101] ④ The actual first year cumulative oil production of QH1-1 well production dynamic history parameters is 3240t.

[0102] (2) According to the QH1-1 well basic database of step (1), the geological model is established by using the reservoir numerical simulation software eclipse, including reservoir porosity distribution field, permeability distribution field, oil saturation distribution field, formation pressure distribution field and the like. The fracture network coverage volume SRV of each fracturing section of shale oil horizontal well microseismic monitoring is introduced into the geological model to obtain the productivity prediction model.

[0103] (3) The productivity prediction model established in step (2) is used to predict the first year cumulative oil production of shale oil horizontal well as 24923t, and compared with the actual production dynamic history of the first year cumulative oil production to calculate the effective fracture network reconstruction volume as 464.1×10 4 m 3 .

[0104] 2. A wicking model considering fluid pressure and capillary force is established to calculate the wicking wave volume. Specifically, the following contents are included:

[0105] ​(1) Obtain the downhole core of the reservoir or the same block and the same layer of the horizontal well of QH1-1 well, and make the rock of the reservoir section into a standard rock sample with a diameter of 2.5 cm and a length of 5 cm. Place the standard rock sample in a 100°C oven and dry it to a constant weight;

[0106] (2) Use a porosity tester to test the porosity of the dried standard rock sample in step (1) using helium as the working medium. The porosity is 8.6%;

[0107] (3) Conduct a core imbibition experiment to test the imbibition amount with respect to the imbibition time. According to the imbibition model formula (2), the experimental data are plotted as a double logarithmic curve of the imbibition amount per unit area and the imbibition time, as shown in Figure 3 . The curve is fitted with a linear function, and the linear function expression is y = 0.4478x - 1.7621. The coefficients B and C are 0.0173 and 0.4478, respectively.

[0108] (4) According to the total fracturing fluid volume of 28650 m 3 , the imbibition time is 14400 min, and the total imbibition area of the QH1-1 well volume fracturing full well section fracture is 1.42 x 10 5 m 2 .

[0109] (5) According to the imbibition sweep volume calculation basic parameters (as shown in Table 2), combined with the total imbibition area of the QH1-1 well volume fracturing full well section fracture and the porosity of the standard rock sample, the imbibition sweep volume of the QH1-1 well is calculated to be 3118.0 m 3 .

[0110] Table 2 Imbibition sweep volume calculation basic parameters

[0111]

[0112]

[0113] 3. According to the shale oil reservoir physical property parameters, the horizontal section length is 1700 m, the oil layer thickness is 15.5 m, the well spacing is 400 m, the oil layer drilling rate is 79.5%, and the effective fracture network modification volume and imbibition sweep volume calculated in steps (1) and (2) are combined to calculate the fracture network sweep coefficient, which is 0.55.

[0114] In summary, the shale oil horizontal well volume fracturing fracture network sweep coefficient can be comprehensively evaluated based on the effective fracture network reconstruction volume, the imbibition sweep volume and the quantitative calculation of the sweep coefficient of the fracture network according to the reservoir parameters of the horizontal well.

[0115] As shown in the figure, the embodiment of the present application also provides a shale oil horizontal well volume fracturing fracture network sweep coefficient comprehensive evaluation device, which comprises, Figure 4

[0116] The first data unit is used for obtaining the data of the shale oil horizontal well volume fracturing field, and obtaining the effective fracture network reconstruction volume according to the data of the field.

[0117] The second data unit is used for obtaining the data of the shale oil horizontal well core, and obtaining the imbibition sweep volume according to the data of the core.

[0118] The sweep coefficient unit is used for obtaining the fracture network sweep coefficient according to the effective fracture network reconstruction volume, the imbibition sweep volume and the data of the shale oil horizontal well volume fracturing field.

[0119] The first data unit further comprises,

[0120] The parameter acquisition module is used for obtaining the reservoir physical property parameters of the shale oil horizontal well volume fracturing field, the basic parameters of the shale oil horizontal well, the microseismic monitoring parameters of the shale oil horizontal well volume fracturing and the historical parameters of the horizontal well production dynamics, and constructing a shale oil horizontal well basic database.

[0121] The reconstruction volume module is used for establishing a productivity prediction model of the shale oil horizontal well according to the shale oil horizontal well basic database, and correcting the fracture network volume by using the oil reservoir numerical simulation production history fitting method to obtain the effective fracture network reconstruction volume V ESRV .

[0122] The second data unit further comprises,

[0123] The porosity module is used for obtaining the porosity of the standard rock sample made of the core drilled downhole by the shale oil horizontal well in the reservoir or the shale oil horizontal well in the same block and the same layer.

[0124] The total area module is used for obtaining the total fracture imbibition area of the shale oil horizontal well according to the imbibition experimental data of the standard rock sample.

[0125] ​The swept volume module is used for obtaining the swept volume according to the total fracture infiltration area of the shale oil horizontal well, the porosity of the standard rock sample and the swept volume of the shale oil horizontal well.

[0126] Finally, it should be noted that: the above only for the preferred embodiments of the present application, and not for limiting the present application, although with reference to the foregoing embodiments of the present application has been described in detail, for those skilled in the art, it still can be modified, or the equivalent replacement of part of the technical features, which are recorded in the foregoing embodiments of the technical solutions, within the spirit and principles of the present application, any modification, equivalent replacement, improvement, etc., should be included within the scope of the present application.

Claims

1. A shale oil horizontal well volumetric fracturing fracture network sweep efficiency comprehensive evaluation method, characterized in that, The shale oil horizontal well volume fracturing mine field data are acquired, and an effective fracture network reconstruction volume is acquired according to the mine field data. The shale oil horizontal well volume fracturing mine field reservoir physical property parameters include reservoir burial depth, effective thickness, original formation pressure, reservoir temperature, formation fluid parameters, average porosity, average permeability, and average oil saturation. The method comprises the following steps: obtaining reservoir physical property parameters, basic parameters of a shale oil horizontal well, volume fracturing microseismic monitoring parameters and production dynamic history parameters of a shale oil horizontal well, and constructing a shale oil horizontal well basic database; establishing a shale oil horizontal well productivity prediction model according to the shale oil horizontal well basic database, and correcting the fracture network volume by using a reservoir numerical simulation production history matching method to obtain an effective fracture network reconstruction volume ; ; wherein is the effective fracture network reconstruction volume, 10 4 m 3 ; is the cumulative oil production of the shale oil horizontal well at a certain time, ton; is the cumulative oil production of the shale oil horizontal well at a certain time, ton; is the fracture network volume, 10 4 m 3 ; is the fracture section number; n is the fracture section number, section; The application relates to a method for calculating the imbibition swept volume of a shale oil horizontal well, which comprises the following steps: obtaining the data of a shale oil horizontal well core, and obtaining the imbibition swept volume according to the data of the core; including the following steps: obtaining the porosity of a standard rock sample made of the core drilled downhole in the reservoir of the shale oil horizontal well or the same layer shale oil horizontal well in the same block; obtaining the total fracture imbibition area of the whole well section of the shale oil horizontal well according to the imbibition experimental data of the standard rock sample; and calculating the imbibition swept volume according to the total fracture imbibition area of the whole well section of the shale oil horizontal well, the porosity of the standard rock sample and the imbibition swept volume, wherein the imbibition swept volume is calculated by the following formula, ; wherein, is the imbibition swept volume; is the porosity of the standard rock sample; is the surface tension; is the wetting contact angle; is the rock pore radius; is the fracture area; is the imbibition liquid viscosity; is the imbibition time. According to the data of effective fracture network reconstruction volume, imbibition wave and volume and shale oil horizontal well volume fracturing field, the fracture network wave coefficient is calculated by the following formula, ; in the formula, is the fracture network wave coefficient, dimensionless; is the length of the horizontal section of the shale oil horizontal well; is the thickness of the oil layer; is the well spacing of the shale oil horizontal well; s is the drilling rate of the oil layer; is the effective fracture network reconstruction volume; is the imbibition wave and volume.

2. The method of claim 1, wherein, The shale oil horizontal well basic parameters include horizontal section length, fracturing section number, and total fracturing fluid volume. The shale oil horizontal well volume fracturing microseismic monitoring parameters include shale oil horizontal well microseismic monitoring corresponding fracture network volume SRV of each fracturing section. The horizontal well production dynamic history parameters include actual cumulative oil production within a certain time. The shale oil horizontal well basic parameters further include, 3. The method of claim 2, wherein, Shale oil horizontal well oil layer thickness, horizontal well spacing, and oil layer drilling rate. The shale oil horizontal well volume fracturing mine field data are acquired, and an effective fracture network reconstruction volume is acquired according to the mine field data.

4. A shale oil horizontal well volumetric fracture network sweep efficiency comprehensive evaluation device, characterized in that, The shale oil horizontal well volume fracturing mine field reservoir physical property parameters include reservoir burial depth, effective thickness, original formation pressure, reservoir temperature, formation fluid parameters, average porosity, average permeability, and average oil saturation. The shale oil horizontal well basic parameters include horizontal section length, fracturing section number, and total fracturing fluid volume. The volume module is used for establishing a productivity prediction model of the shale oil horizontal well according to a shale oil horizontal well basic database, and a fracture network volume is corrected by using a reservoir numerical simulation production history fitting method to obtain an effective fracture network reconstruction volume ; ; wherein is the effective fracture network reconstruction volume, 10 4 m 3 ; is actual cumulative oil production of the shale oil horizontal well at a certain time, ton; is predicted cumulative oil production of the shale oil horizontal well at a certain time, ton; is the fracture network volume, 10 4 m 3 ; is a fracturing section number; n is a fracturing section number, section; The shale oil horizontal well volume fracturing microseismic monitoring parameters include shale oil horizontal well microseismic monitoring corresponding fracture network volume SRV of each fracturing section. The horizontal well production dynamic history parameters include actual cumulative oil production within a certain time. The shale oil horizontal well basic parameters further include, Shale oil horizontal well oil layer thickness, horizontal well spacing, and oil layer drilling rate. The shale oil horizontal well volume fracturing mine field data are acquired, and an effective fracture network reconstruction volume is acquired according to the mine field data. The shale oil horizontal well volume fracturing mine field reservoir physical property parameters include reservoir burial depth, effective thickness, original formation pressure, reservoir temperature, formation fluid parameters, average porosity, average permeability, and average oil saturation. The shale oil horizontal well basic parameters include horizontal section length, fracturing section number, and total fracturing fluid volume. The shale oil horizontal well volume fracturing microseismic monitoring parameters include shale oil horizontal well microseismic monitoring corresponding fracture network volume SRV of each fracturing section. The horizontal well production dynamic history parameters include actual cumulative oil production within a certain time. The shale oil horizontal well basic parameters further include, Shale oil horizontal well oil layer thickness, horizontal well spacing, and oil layer drilling rate. a total area module for obtaining a total fracture imbibition area of a shale oil horizontal well full hole section according to imbibition experiment data of a standard rock sample; a swept volume module for calculating an imbibition swept volume according to the total fracture imbibition area of the shale oil horizontal well full hole section, porosity of the standard rock sample and imbibition swept volume of basic parameters, ; wherein, is the imbibition swept volume; is the porosity of the standard rock sample; is the surface tension; is the wetting contact angle; is the rock pore radius; is the fracture area; is the imbibition liquid viscosity; is the imbibition time; A sweep efficiency unit is used to obtain a fracture network sweep efficiency according to data of an effective fracture network reconstruction volume, imbibition sweep volume and shale oil horizontal well volume fracturing field, and the following formula is used for calculation, ; wherein, is the fracture network sweep efficiency, dimensionless; is the length of the horizontal section of the shale oil horizontal well; is the oil layer thickness; is the spacing of the shale oil horizontal well; s is the oil layer drilling rate; is the effective fracture network reconstruction volume; is the imbibition sweep volume.

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