Method for determining horizontal well pattern density of shale oil and gas reservoir based on integration of technology and economy

Abstract

The present invention provides a method for determining the horizontal well pattern density of a shale oil and gas reservoir based on the integration of technology and economy, belonging to the technical field of horizontal well development design of shale gas reservoirs. The method is realized by determining the optimal well spacing of horizontal wells in a shale gas reservoir and determining the economically optimal horizontal section length of horizontal wells in a shale gas reservoir. Among them, the optimal well spacing of the horizontal well is determined by formula V, that is, #imgabs0#, and L xmin is the technically optimal well spacing, #imgabs1# is the economically optimal well spacing, and #imgabs2# is the well spacing L xi The net present value of the unit area finance below. The present invention can comprehensively consider the optimal well spacing and the optimal horizontal section length of the horizontal well, so as to form an optimized scheme for determining the horizontal well pattern density, which is beneficial to the efficient development of shale gas reservoirs.

Description

Technical Field

[0001] The present invention relates to the technical field of horizontal well development design for shale gas reservoirs. Specifically, it relates to a method for determining the well pattern density of horizontal wells in shale oil and gas reservoirs based on the integration of technology and economy. Background Art

[0002] China is rich in shale gas resources, and the proven reserves account for an increasing proportion of unconventional resources. The efficient development of shale gas is of great significance for improving China's energy structure in the future. With the deeper understanding of geology and the upgrading of reservoir stimulation technologies, the previously used well pattern parameters for shale gas reservoir development in North America have shown a certain degree of inadaptability. For example, at a well spacing of 600 m, there is a large amount of remaining gas that has not been exploited, and it is difficult to guarantee the economic benefits of subsequent infill wells; when a well spacing of 300 m is implemented in some platforms, the well interference phenomenon is prominent, which not only affects the fracturing effect of new wells but also causes water flooding to the normal production of adjacent wells, bringing challenges to subsequent stimulation measures.

[0003] The Chinese patent application with the publication number CN110984951A and the publication date of April 10, 2020 provides a method for deploying a well pattern for shale oil development. The method includes: determining a plurality of shale oil sweet spot boxes; determining a pilot development box from the plurality of shale oil sweet spot boxes, where the distance between two adjacent pilot development boxes is not greater than the predicted fracture height; determining the trajectory deployment azimuth of the horizontal well in its corresponding pilot development box according to the predicted fracture distribution trajectory and the pre-calculated maximum principal stress direction of the horizontal well; determining the horizontal section length of the horizontal well according to the planar distribution range of the sweet spot body in the pilot development box; determining the well spacing between two adjacent horizontal wells according to the predicted fracture length; and determining the well pattern deployment scale according to the corresponding relationship between the wellhead of each predicted horizontal well and the target point of the horizontal well and the spatial position relationship of horizontal wells in different formations. The technical solution provided by this patent application can optimize the three-dimensional spatial configuration of horizontal wells, thereby increasing the single-well production and fracture-controlled reserves during the development of continental shale oil. However, this application does not involve separately determining the optimal well spacing and optimal horizontal section length of horizontal wells, nor does it involve the content of determining the well pattern density by comprehensively considering the optimal well spacing and optimal horizontal section length of horizontal wells.

[0004] The Chinese patent application with the publication number CN104141481A and the publication date of November 12, 2014 provides a method for arranging horizontal wells in ultra-low permeability tight oil reservoirs; the Chinese patent application with the publication number CN103362485A and the publication date of October 23, 2013 provides a method for exploiting heavy oil reservoirs by gravity-assisted nanofluid flooding and its well pattern structure. However, these two patent applications also do not involve separately determining the optimal well spacing and optimal horizontal section length of horizontal wells, let alone the content of determining the well pattern density by comprehensively considering the optimal well spacing and optimal horizontal section length of horizontal wells. Summary of the Invention

[0005] The object of the present invention is to solve at least one of the above deficiencies existing in the prior art. For example, one of the objects of the present invention is to provide a method for determining the horizontal well pattern density of shale gas wells based on the integration of technology and economy, which can comprehensively consider and optimize the well spacing and horizontal section length of horizontal wells in shale gas reservoirs, so as to determine the horizontal well pattern density of shale gas wells based on the integration of technology and economy.

[0006] To achieve the above object, the present invention provides a method for determining the horizontal well pattern density of shale gas wells based on the integration of technology and economy. The method is realized by determining the optimal well spacing of horizontal wells in shale gas reservoirs and the economically optimal horizontal section length of horizontal wells in shale gas reservoirs. Among them,

[0007] The optimal well spacing of the horizontal well is determined by Equation V,

[0008] The Equation V is

[0009] wherein, L xbest is the optimal well spacing of the horizontal well, L xmin is the technically optimal well spacing, is the economically optimal well spacing, is the net present value of the unit area finance at the well spacing L xi below.

[0010] In an exemplary embodiment of the present invention, the technically optimal well spacing L xmin can be obtained by Equation IV. The Equation IV is L xmin = max{L x1 , L x2}, wherein, L x1 is the economically minimum well spacing, which means the well spacing obtained when the ultimate recoverable reserve evaluated by a single well is reduced to the critical value of the financial internal rate of return as the well spacing decreases; L x2 is the technically minimum well spacing.

[0011] In an exemplary embodiment of the present invention, the L x2 can be obtained by Equation III. The Equation III is L x2 = 2x f , wherein, x f is the half-length of the fracture, which is obtained by Equation I. The Equation 1 is x f = f(Q, L perf , N perf , M l ), wherein, Q is the construction displacement, L perf is the cluster spacing, N perf is the number of clusters, M l is the liquid volume.

[0012] In an exemplary embodiment of the present invention, the economically optimal horizontal section length can be obtained by Equation VIII, and Equation VIII is where L ybest is the economically optimal horizontal section length, and IRR Ly represents the financial internal rate of return when the horizontal section length is L y .

[0013] In an exemplary embodiment of the present invention, the determination method of the economically optimal horizontal section length can be as follows: under the condition of determining the optimal well spacing, economically optimal well spacing or technically optimal well spacing, Equation VI and Equation VII are used to calculate the ultimate recoverable reserves and single-well cost of single-well evaluation at different horizontal section lengths, and then the financial internal rate of return is calculated accordingly to obtain the financial internal rate of return at different horizontal section lengths. The maximum value of the financial internal rate of return is the economically optimal horizontal section length.

[0014] In an exemplary embodiment of the present invention, Equation VI can be EUR = Aln(L y ) + B, where EUR is the ultimate recoverable reserves of single-well evaluation, A and B are equation coefficients, and L y is the horizontal section length. In addition, the functional relationship between EUR and the horizontal section length in Equation VI can be obtained by regression using the field statistical method. Additionally, Equation VII can be where C and D are equation coefficients, L y is the horizontal section length, and CW is the single-well cost. For example, the functional relationship between the single-well cost and the horizontal section length in Equation VI can be obtained by regression using the field statistical method.

[0015] In an exemplary embodiment of the present invention, the yield threshold value can be 8%, however, the present invention is not limited thereto, and other yield threshold values (for example, 5-10%) are also possible.

[0016] In an exemplary embodiment of the present invention, the method for determining the horizontal well pattern density of a shale gas reservoir is applicable to shale gas reservoirs with actual block heterogeneity.

[0017] Compared with the prior art, the beneficial effects of the present invention include at least one of the following:

[0018] (1) The present invention mainly proposes technical measures for optimizing the reasonable well pattern density of horizontal wells, but this method is also applicable to the optimization of vertical well patterns, expanding the adaptability of the well pattern optimization method, and for the first time proposing horizontal section length optimization measures;

[0019] (2) The empirical parameters used in the present invention mainly come from actual fields, have strong practicability, and the evaluation results are more objective and real than those using experiments or pure numerical simulations;

[0020] (3) The design concept of the method for determining the horizontal well pattern density in shale gas reservoirs of the present invention is novel, the empirical parameters are reliable, and the on-site implementation is easy, providing a new feasible technical means for promoting the efficient development of shale gas reservoirs. Description of the Drawings

[0021] Through the following description in conjunction with the drawings, the above and other objects and / or features of the present invention will become clearer, where:

[0022] Figure 1 The flowchart of an exemplary embodiment of the method for determining the horizontal well pattern density in shale oil and gas reservoirs based on the integration of technology and economy of the present invention is shown;

[0023] Figure 2 The average half-fracture length and fracture area under different fluid injection intensities in an exemplary embodiment of the method for determining the horizontal well pattern density in shale oil and gas reservoirs based on the integration of technology and economy of the present invention are shown;

[0024] Figure 3 The pressure drop funnel spread range diagram in an exemplary embodiment of the method for determining the horizontal well pattern density in shale oil and gas reservoirs based on the integration of technology and economy of the present invention is shown;

[0025] Figures 4A to 4E The pressure spread diagrams at different well spacings (200, 300, 400, 500, 600 m) in an exemplary embodiment of the method for determining the horizontal well pattern density in shale oil and gas reservoirs based on the integration of technology and economy of the present invention are shown;

[0026] Figure 5 The economic evaluation result diagram in an exemplary embodiment of the method for determining the horizontal well pattern density in shale oil and gas reservoirs based on the integration of technology and economy of the present invention is shown;

[0027] Figure 6 The relationship diagram between the horizontal section length excluding geological influence factors and the EUR function in an exemplary embodiment of the method for determining the horizontal well pattern density in shale oil and gas reservoirs based on the integration of technology and economy of the present invention is shown.

[0028] Description of the Reference Numerals:

[0029] S10 - Determination of the optimal well spacing of horizontal wells, S11 - Determination of the maximum well spacing of horizontal wells, S11a - Determination of the horizontal fracture length, S11b - Determination of the spread range after 20 years of exploitation, S12 - Determination of the minimum well spacing of horizontal wells, S12a - Technical minimum well spacing, S12b - Economic minimum well spacing;

[0030] S20 - Determination of the optimal horizontal section length of horizontal wells, S21 - Determination of the relationship between EUR and the horizontal section length, S22 - Determination of the relationship between cost and the horizontal section length. Detailed Description of the Invention

[0031] In the following, the method for determining the horizontal well pattern density of shale oil and gas reservoirs based on the integration of technology and economy of the present invention will be described in detail in conjunction with exemplary embodiments. The method of the present invention is applicable to shale gas reservoirs and shale oil reservoirs.

[0032] Generally speaking, the method of the present invention determines the hydraulic fracture length according to the natural fracture development degree of the shale reservoir in a specific block, combines the measured core permeability in the laboratory, and uses fracture propagation simulation and monitoring technical means. The EUR of a single well under different well spacings and different horizontal section lengths is simulated respectively by a numerical simulator, and the block utilization degree and net present value are calculated to realize the reasonable optimization of the horizontal well pattern of shale gas wells. This method can take into account both the well spacing and the horizontal section length, and at the same time consider the influence of reservoir heterogeneity, and finally form a reasonable well spacing optimization method for shale gas reservoirs with the best economy or the best technology, providing an effective technical means for further improving the development efficiency of shale gas.

[0033] As Figure 1 shown, in an exemplary embodiment of the present invention, the method for determining the horizontal well pattern density of shale oil and gas reservoirs based on the integration of technology and economy specifically includes: determining the optimal well spacing of horizontal wells in shale gas reservoirs S10 ( Figure 1 abbreviated as determining the optimal well spacing of horizontal wells in the following), and determining the optimal horizontal section length of horizontal wells in shale gas reservoirs S20 ( Figure 1 abbreviated as determining the optimal horizontal section length of horizontal wells in the following), which are two parts.

[0034] Step S10 is to determine the optimal well spacing of horizontal wells, which includes sub-step S11 of determining the maximum well spacing of horizontal wells based on the determination of horizontal fracture length (or the module for determining horizontal fracture length) S11a and the determination of the swept range in 20 years of production (or the module for determining the swept range in 20 years of production) S11b, and sub-step S12 of determining the minimum well spacing of horizontal wells based on the technical minimum well spacing (or the module for technical minimum well spacing) S12a and the economic minimum well spacing (or the module for economic minimum well spacing) S12b. It should be noted that unless otherwise clearly stated below, the four modules S11a, S11b, S12a, and S12b may not have a strict order; similarly, unless otherwise clearly stated below, the two sub-steps S11 and S12 may also not have a strict order.

[0035] Specifically, for the determination of the hydraulic fracture length of module S11a, it mainly relies on a fracture propagation simulator and the actual fracturing construction data of the block to establish a functional relationship between the hydraulic fracture length and the fracturing construction parameters

[0036] x f = f(H, Q, L perf , N perf , M l ) (I)

[0037] In Formula I, x f is the half-length of the fracture, H is the fluid injection strength, Q is the construction displacement, L perf is the cluster spacing, N perf is the number of clusters, M l is the fluid volume.

[0038] For the determination of the sweep range of the heterogeneous reservoir with natural fractures in the 20-year exploitation of Module S11b (abbreviated as the determination of the sweep range in the 20-year exploitation), it mainly refers to establishing a gas reservoir numerical simulation model of the heterogeneous reservoir with natural fractures based on the fracture development degree and distribution characteristics interpreted from the three-dimensional high-resolution seismic data of the actual block, combined with the matrix permeability measured in the laboratory core, and adding hydraulic fracture parameters to the hydraulic fracture half-length model established by Formula I, and simulating according to the 20-year production of the gas well to obtain the outer sweep distance L of the hydraulic fracture after the full life cycle of the gas well under different natural fracture development degrees and different core permeabilities. Obtain the maximum well spacing L of the horizontal well xmax

[0039] L xmax = x f + L (II)

[0040] Regarding the determination of the minimum well spacing of the horizontal well in Sub-step S12, the minimum well spacing of the horizontal well is the larger value of the economic minimum well spacing and the technical minimum well spacing. The economic minimum well spacing of Module S12b mainly refers to that as the well spacing of the gas well decreases, the well interference phenomenon becomes prominent, and the EUR of a single well (Estimated Ultimate Recovery of a single well, that is, the finally recoverable reserve evaluated for a single well) will gradually decrease. When the EUR of a single well decreases to the financial internal rate of return of 8%, the obtained well spacing is the economic minimum well spacing L x1 . The technical minimum well spacing of S12a, that is, the critical well spacing for hydraulic fracture interference between fractures, then

[0041] L x2 = 2x f (III)

[0042] That is, there is the minimum well spacing of the horizontal well

[0043] L xmin = max{L x1 , L x2} (IV)

[0044] Regarding the determination of the optimal well spacing for horizontal wells in step S10, the optimal well spacing for horizontal wells mainly includes the technically optimal well spacing and the economically optimal well spacing. The technically optimal well spacing refers to the well spacing that maximizes the overall utilization degree of the block when the internal financial rate of return of a single well is not less than 8%, that is, the technically optimal well spacing is equal to the minimum well spacing of horizontal wells. The economically optimal well spacing is the well spacing that maximizes the net present value of the finance per unit area of the block while taking into account that the internal financial return is not less than 8% and the overall utilization degree of the block. Then the optimal well spacing has

[0045]

[0046] The well spacing is L xi The net present value of the finance per unit area below.

[0047] The upper limit value of the economically optimal well spacing should be less than the maximum well spacing, because as the well spacing increases, the NPV of a single well increases, but the overall utilization degree of the block gradually decreases. If the well spacing exceeds the maximum well spacing, there will be unutilized reserves.

[0048] Regarding the determination of the relationship between EUR and the horizontal section length in sub-step S21, the establishment of the functional relationship between EUR and the horizontal section length mainly refers to using the field statistical method to regress the functional relationship formula between EUR and the horizontal section length, that is, there is

[0049] EUR = Aln(L y ) + B (VI)

[0050] In the formula, A and B are the equation coefficients, and L y Is the horizontal section length.

[0051] The above-mentioned field statistical method, that is, statistically counting the EUR and the horizontal section length of the implemented shale gas wells, and then finding the mathematical functional relationship between the two. This relationship is unknown in advance and finally finds a relationship that meets the test requirements through continuous testing, that is, formula VI. The relationship between the single well cost and the horizontal section length is the same.

[0052] Regarding the determination of the relationship between the cost and the horizontal section length in sub-step S22, it refers to the establishment of the functional relationship between the single well cost and the horizontal section length, mainly referring to using the field statistical method to regress the functional relationship formula between the single well cost (CW) and the horizontal section length, that is, there is

[0053]

[0054] In the formula, C and D are the equation coefficients, and L y Is the horizontal section length.

[0055] Formula VI is a logarithmic relationship, and formula VII is an exponential relationship. The coefficients A and B are obtained through calculation, that is, obtained by regressing the actual field data. The same is true for C and D.

[0056] Regarding the determination of the optimal horizontal section length of S20, it refers to the determination of the economically optimal horizontal section length, that is, under the condition of determining the optimal well spacing (economically optimal well spacing or technically optimal well spacing), the EUR per well and the cost per well at different horizontal section lengths are calculated using Formulas VI and VII, and then the financial internal rate of return is calculated accordingly to obtain the financial internal rate of return at different horizontal section lengths. The maximum value of the financial internal rate of return is the economically optimal horizontal section length.

[0057] That is

[0058]

[0059] Among them, IRR Ly represents the financial internal rate of return when the horizontal section length is L y at that time.

[0060] So far, the optimization of the horizontal well pattern density of shale gas reservoirs considering the actual reservoir heterogeneity has been achieved.

[0061] To determine the hydraulic fracture length of a certain shale gas field, based on the fracturing construction parameters of a certain shale gas field, simulation is carried out using a fracture propagation simulator. The parameters used in the model are shown in Table 1.

[0062] Table 1 Basic parameters of fracture propagation simulation

[0063]

[0064] The functional relationship between the hydraulic fracture length and the fracturing construction parameters is:

[0065] x f = f(45, 17.5, 12.9, 7, 1743)

[0066] The simulation results are as Figure 2 shown.

[0067] The simulation results of fracture network propagation show that with the increase of the fluid injection intensity, both the average half fracture length and the fracture area increase, but the increasing amplitude gradually slows down. After the fracture half length extends to 100 meters, increasing the fluid injection intensity does not significantly increase the fracture half length. This is because the presence of natural fractures in the reservoir increases the complexity of the artificial fractures generated by hydraulic fracturing, but at the same time limits the extension of the hydraulic fracture length.

[0068] The average permeability of the target block is 300 nD; the average porosity is 6%; the average gas saturation is 40%. Based on the physical property parameters of the block, a three-dimensional geological model is established using the embedded discrete grid technology. Five small layers are set vertically, and the horizontal well is located at the center of the fourth small layer. Assuming the hydraulic fracture half length is 100 meters, the influence range of the pressure drawdown funnel during 20 years of simulation production is simulated. The simulation results are as Figure 3 shown.

[0069] The numerical simulation results show that the outer influence distance L of the hydraulic fracture is 400 m. The maximum well spacing L of the horizontal well is obtained xmax = x f + L = 500 m.

[0070] Six groups of models with well spacings of 200 m, 300 m, 400 m, 500, 600 m, and > 600 m were designed in the target block respectively. The reservoir pressure distribution after 20 years of production is as Figures 4A to 4E shown. It can be seen that when the gas well spacing is greater than or equal to 500 m, the pressure drop only occurs near the hydraulic fracture of the gas well, and the pressure drop influence areas of each gas well do not overlap. The critical well spacing for a gas well to be affected by the pressure of adjacent wells is 500 m. This further proves that the maximum well spacing of the horizontal well is 500 m.

[0071] After obtaining the EUR of a single well and the reservoir utilization degree through numerical simulation, the internal rate of return (IRR) and net present value (NPV) of each group of models can be calculated accordingly. The calculation results are shown in Table 2.

[0072] Table 2 Economic evaluation results

[0073]

[0074]

[0075] When the well spacing is 200 m, the internal rate of return is 13.5%, then the economic minimum well spacing L x1 is less than 200 m. L x2 = 2x f = 200 m. In this example, the minimum well spacing L of the horizontal well xmin = max{L x1 , L x2} = 200 m.

[0076] Refer to Figure 5 the economic evaluation result diagram. The NPV per unit area of the target block reaches the maximum when the well spacing is between 300 and 400 m. At this time, the financial internal rate of return is not less than 8% and less than the maximum well spacing of 500 m. Therefore, the economic optimal well spacing in this example is 300 - 400 m.

[0077]

[0078] Taking 108 wells in the studied target gas field as samples for statistical analysis, it is found that after excluding geological factors (Longyi 1 1 thickness, gas content, porosity), the EUR has a natural logarithmic relationship with the horizontal section length.

[0079] The regression trend line can obtain the relationship between the horizontal section length and the unit geological EUR as:

[0080] y = 104.619ln(x) - 704.145 (Formula 1)

[0081] The functional relationship between the single - well cost (CW) and the horizontal section length is obtained by regression, that is

[0082]

[0083] Reference Figure 6 , applying the above two formulas to calculate the single - well EUR and single - well cost at different horizontal section lengths, and then calculating the financial internal rate of return based on this. The calculation results are shown in Table 3.

[0084] Table 3 Economic evaluation results of horizontal section length

[0085] Horizontal section length (m) Single well EUR (100 million m³) Single well cost (10,000 yuan) IRR (%) 1000.00 0.96 4061.60 18.55 1500.00 1.26 4584.29 32.81 2000.00 1.51 5161.94 38.59 2500.00 1.73 5800.35 40.51 3000.00 1.93 6505.91 39.60 3500.00 2.10 7285.66 33.22 4000.00 2.26 8147.43 30.00 4500.00 2.40 9099.82 21.00

[0086] When the horizontal section length is 2500m, the internal rate of return IRR is the highest, which is 40.51%.

[0087]

[0088] Although the present invention has been described above in conjunction with exemplary embodiments and the accompanying drawings, those of ordinary skill in the art should clearly understand that various modifications can be made to the above - mentioned embodiments without departing from the spirit and scope of the claims.

Claims

1. A method for determining the horizontal well pattern density of a shale oil and gas reservoir based on the integration of technology and economy, characterized in that, the method for determining the horizontal well pattern density of the shale oil and gas reservoir is realized by determining the optimal well spacing of the horizontal well in the shale oil and gas reservoir and determining the economically optimal horizontal section length of the horizontal well in the shale oil and gas reservoir, wherein, the optimal well spacing of the horizontal well is determined by Equation V, The formula V is Among them, L xbest is the optimal well spacing of the horizontal well, L xmin is the optimal well spacing for technology, obtained from Equation IV, and Equation IV is L xmin = max{L x1 , L x2}, where L x1 is the minimum economic well spacing, L x2 is the minimum technical well spacing, and L x2 is obtained from Equation III, and Equation III is L x2 = 2x f , where x f is the half-length of the fracture, and x f is obtained from Equation I, and Equation I is x f = f(Q, L perf , N perf , M l ), where Q is the construction displacement, L perf is the cluster spacing, N perf is the number of clusters, M l is the liquid volume. is the economically optimal well spacing, is the well spacing L xi is the net present value of the unit area's finance, L xmax is the maximum well spacing of horizontal wells, obtained from Equation II, and Equation II is L xmax = x f + L, where L is the affected distance outside the hydraulic fracture; the economically optimal horizontal section length is obtained by Equation VIII, The formula VIII is Among them, L ybest is the economic optimal horizontal section length, and IRR Ly represents the financial internal rate of return when the horizontal section length is L y at that time, the determination method of the economically optimal horizontal section length is: under the condition of determining the optimal well spacing, the economically optimal well spacing or the technically optimal well spacing, use Equation VI and Equation VII to calculate the ultimately recoverable reserves and the single-well cost evaluated for different horizontal section lengths, and then calculate the financial internal rate of return accordingly to obtain the financial internal rate of return for different horizontal section lengths. The maximum value of the financial internal rate of return is the economically optimal horizontal section length, Equation VI is EUR = Aln(L y ) + B, where EUR is the ultimate recoverable reserve evaluated for a single well, A and B are the coefficients of the equation, and L y is the horizontal section length. Formula VII is C and D are coefficients of the equation, L y is the length of the horizontal section, and CW is the cost of a single well.

2. The method for determining the horizontal well pattern density of a shale oil and gas reservoir based on the integration of technology and economy according to Claim 1, characterized in that, the meaning of the economically minimum well spacing is the well spacing obtained when the ultimately recoverable reserves evaluated for a single well are reduced to the critical value of the financial internal rate of return as the well spacing decreases.

3. The method for determining the horizontal well pattern density of a shale oil and gas reservoir based on the integration of technology and economy according to Claim 1, characterized in that, the functional relationship between EUR and the horizontal section length in Equation VI is obtained by regression using the field statistics method.

4. The method for determining the horizontal well pattern density of a shale oil and gas reservoir based on the integration of technology and economy according to Claim 1, characterized in that, the functional relationship between the single-well cost and the horizontal section length in Equation VII is obtained by regression using the field statistics method.

5. The method for determining the horizontal well pattern density of a shale oil and gas reservoir based on the integration of technology and economy according to Claim 2, characterized in that, the critical value of the rate of return is 8%.

6. The method for determining the horizontal well pattern density of a shale oil and gas reservoir based on the integration of technology and economy according to Claim 1, characterized in that, the method for determining the horizontal well pattern density of the shale oil and gas reservoir is applied to the shale oil and gas reservoir with actual block heterogeneity.

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