Method and device for controlling production system after fracturing during the whole life cycle of a fracturing well

Abstract

The present application provides a method and device for regulating the post-fracturing production system of a fracturing well throughout its life cycle, including: obtaining the fracturing transformation volume of different shale wells during the fracturing stage; determining the fracturing transformation plan for the target well based on the pressure transformation volume of different wells; obtaining the full-well absorption energy enhancement volume of different shale wells during the well shut-in stage; determining the optimal well shut-in condition of the target well based on the full-well absorption energy enhancement volume of different wells; obtaining the oil production contribution matrix pore volume of different shale wells during the backflow stage; determining the backflow plan of the target well based on the oil production contribution matrix pore volume of different wells; obtaining the single-well recoverable reserves of different shale wells during the well opening and production stage; determining the production plan of the target well based on the single-well recoverable reserves of the oil wells under the specified lifespan of different wells. It can continuously optimize and regulate the plans of the subsequent fracturing construction stage, well shut-in stage, backflow stage and well opening and production stage during the construction of the fracturing well, and improve the final recovery rate of the single well.

Description

Technical Field

[0001] The present application relates to the technical field of unconventional oil and gas development, and in particular to a method and device for regulating the post-fracturing production system of a fracturing well throughout its entire life cycle. Background Art

[0002] Unconventional oil and gas reservoirs, especially shale reservoirs, have complex geological conditions, and are characterized by self-generation and self-storage, large-scale continuous accumulation, low porosity, low permeability, and diverse gas storage modes. They generally have no natural production capacity or low production, and require large-scale hydraulic fracturing and horizontal well technology for economic exploitation. Secondly, environmental protection requirements are increasing, and capacity construction is becoming more difficult. Thirdly, due to the continuous increase in land acquisition and borrowing costs, pre-drilling costs, and relocation costs, the cost of oil and gas field capacity construction continues to rise, and reducing development costs is imminent.

[0003] At present, the fracturing design and construction plan dominated by the initial geological factors will continue to have problems as the construction progresses. Therefore, there is an urgent need for a method for regulating the post-fracturing production system of the whole life cycle of the fracturing well, so as to continuously evaluate the fracturing construction effect of the construction well during the fracturing well construction process, and continuously optimize and regulate the subsequent fracturing construction stage, well shut-in stage, flowback stage and well opening production stage according to the inversion parameters, so as to improve the ultimate recovery rate of the single well. Summary of the invention

[0004] The embodiment of the present application provides a method and device for regulating the post-fracturing production system of a fracturing well throughout its entire life cycle, so as to continuously evaluate the fracturing construction effect of the construction well during the fracturing well construction process, and continuously optimize and regulate the subsequent fracturing construction stage, well shut-in stage, backflow stage and well opening production stage according to the inversion parameters, so as to improve the ultimate recovery rate of a single well.

[0005] In a first aspect, an embodiment of the present application provides a method for controlling the post-fracturing production system of a fracturing well throughout its life cycle, the method being applied to any target shale well, comprising:

[0006] During the fracturing stage, the fracturing construction parameters of other shale wells in the same area were obtained, and numerical simulation was performed using unconventional shale reservoir simulation software to simulate the formation fracture morphology and obtain the fracturing transformation volume of different shale wells;

[0007] Determining a scheme for fracturing the target shale well based on the pressure transformation volumes of different shale wells;

[0008] During the well soaking stage, obtain the full-well imbibition energy enhancement volume of other different shale wells in the same area;

[0009] Determine the optimal well-sucking condition of the target shale well based on the full-well imbibition energy enhancement volume of different shale wells;

[0010] In the flowback stage, the matrix pore volume contributing to oil production of other different shale wells in the same area is obtained;

[0011] Determine the size of the oil nozzle and the flowback scheme of the target shale well based on the matrix pore volume contributed by the oil production of different shale wells;

[0012] During the well production phase, obtain the recoverable reserves of other shale wells in the same area;

[0013] Based on the recoverable reserves of individual oil wells within the specified life span of different shale wells, the production plan of the target shale well is determined.

[0014] In a second aspect, an embodiment of the present application provides a post-fracturing production system control device for a fracturing well throughout its life cycle, the device being applied to any target shale well, comprising:

[0015] The fracturing processing module is used to obtain the fracturing construction parameters of other shale wells in the same area during the fracturing stage, and use unconventional shale reservoir simulation software to perform numerical simulation to simulate the formation fracture morphology and obtain the fracturing transformation volume of different shale wells; based on the pressure transformation volume of different shale wells, determine the fracturing transformation plan for the target shale well;

[0016] A well shut-in processing module is used to obtain the full-well imbibition energy-increasing volumes of other different shale wells in the same area during the well shut-in stage; based on the full-well imbibition energy-increasing volumes of different shale wells, determine the optimal well shut-in condition of the target shale well;

[0017] The flowback processing module is used to obtain the oil production contribution matrix pore volume of other different shale wells in the same area during the flowback stage; based on the oil production contribution matrix pore volume of different shale wells, determine the oil discharge nozzle size and flowback plan of the target shale well;

[0018] The production processing module is used to obtain the single-well recoverable reserves of other shale wells in the same area during the well opening and production stage; based on the single-well recoverable reserves of oil wells under the specified life of different shale wells, determine the production plan of the target shale well.

[0019] In a third aspect, an embodiment of the present application provides a computer device, including: at least one processor and a memory;

[0020] The memory stores computer-executable instructions;

[0021] The at least one processor executes the computer-executable instructions stored in the memory, so that the at least one processor executes the method for controlling the post-fracturing production system of a fractured well throughout its life cycle as described in the first aspect and various possible designs of the first aspect.

[0022] In a fourth aspect, an embodiment of the present application provides a computer-readable storage medium, wherein the computer-readable storage medium stores computer execution instructions. When a processor executes the computer execution instructions, the method for regulating the post-fracturing production system of a fracturing well throughout its life cycle as described in the first aspect and various possible designs of the first aspect is implemented.

[0023] The present application provides a method and device for regulating the post-fracturing production system of a fracturing well during its entire life cycle. In the fracturing stage, the fracturing transformation volume of different shale wells is obtained; based on the pressure transformation volume of different shale wells, a fracturing transformation plan for a target shale well is determined; in the well shut-in stage, the full-well imbibition energy enhancement volume of different shale wells is obtained; based on the full-well imbibition energy enhancement volume of different shale wells, the optimal well shut-in condition of the target shale well is determined; in the flowback stage, the oil production contribution matrix pore volume of different shale wells is obtained; based on the oil production contribution matrix pore volume of different shale wells, the size of the oil nozzle and the flowback plan of the target shale well are determined; in the well opening and production stage, the single-well recoverable reserves of different shale wells are obtained; based on the single-well recoverable reserves of the oil wells within the specified life span of different shale wells, the production plan of the target shale well is determined. During the fracturing well construction process, the fracturing construction effect of the construction well is continuously evaluated, and the plans for the subsequent fracturing construction stage, well shut-in stage, flowback stage and well opening and production stage are continuously optimized and regulated according to the inversion parameters, achieving the technical effect of improving the ultimate recovery rate of a single well. BRIEF DESCRIPTION OF THE DRAWINGS

[0024] In order to more clearly illustrate the technical solutions in the embodiments of the present application or the prior art, the appendix required to be used in the embodiments or the prior art description is described below. Figure 1 After a brief introduction, it is obvious that the drawings described below are some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without any creative work.

[0025] Figure 1 A schematic diagram of a process for controlling the post-fracture production system of a fracturing well during its entire life cycle provided in an embodiment of the present application;

[0026] Figure 2 A schematic diagram of a pressure drop curve and a pressure drop derivative curve provided in an embodiment of the present application;

[0027] Figure 3 A schematic diagram of a double logarithmic curve of standardized pressure and material equilibrium time provided in an embodiment of the present application;

[0028] Figure 4 A structural block diagram of a post-fracturing production system control device for a fracturing well throughout its life cycle provided in an embodiment of the present application;

[0029] Figure 5A schematic diagram of the hardware structure of a computer provided in an embodiment of the present application. DETAILED DESCRIPTION

[0030] In order to make the purpose, technical solution and advantages of the embodiments of the present application clearer, the technical solution in the embodiments of the present application will be clearly and completely described below in conjunction with the drawings in the embodiments of the present application. Obviously, the described embodiments are part of the embodiments of the present application, not all of the embodiments. Based on the embodiments in the present application, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of this application.

[0031] In actual oilfield development operations, as oilfields continue to develop, hundreds or even thousands of wells will be constructed. Fracturing construction schemes dominated by initial geological factors will continue to change or have problems as development progresses. Therefore, there is an urgent need for a production control method that continuously evaluates the fracturing effect of the construction wells during the fracturing well construction process, and continuously optimizes and controls the subsequent fracturing construction, well soaking time determination, and production system based on the inversion parameters to improve the ultimate recovery rate of a single well.

[0032] refer to Figure 1 , Figure 1 This is a flow chart of a method for controlling the post-fracture production system of a fracturing well during its entire life cycle provided in an embodiment of the present application. The execution subject of this method may be a computer. Figure 1 , the method comprising:

[0033] S101: During the fracturing stage, the fracturing construction parameters of other shale wells in the same area are obtained, and numerical simulation is performed using unconventional shale reservoir simulation software to simulate the formation fracture morphology and obtain the fracturing transformation volume of different shale wells.

[0034] Specifically, the fracturing construction pumping parameters and on-site geological parameters of the on-site volume fracturing construction are obtained, and the fracturing construction pumping parameters and on-site geological parameters are input into the reservoir simulation software for numerical simulation. During the numerical simulation process, the fracturing construction pressure drop is fitted to simulate the actual formation fracture expansion morphology, and the fracturing transformation volume of the entire horizontal well section is obtained.

[0035] Among them, the fracturing construction parameters include fracturing construction pumping parameters and on-site geological parameters;

[0036] The fracturing construction pumping parameters include: fracturing fluid viscosity, density and type; the proportion of different types of fracturing fluid; injection time and injection volume of different types of fracturing fluid; proppant density, size and type; injection volume of proppant at different stages; stopping the pump after the pumping is completed, and obtaining the construction pressure drop data through on-site pressure statistics;

[0037] The on-site geological parameters include: Young's modulus and Poisson's ratio of the target formation obtained from uniaxial compression tests.

[0038] Here, the pumping parameters of the fracturing construction in the field can be obtained through statistics.

[0039] Among them, the fracturing construction pumping parameters and on-site geological parameters are input into reservoir simulation software such as eclipse, cmg, and petro for numerical simulation. By simulating the formation fracture morphology, the fracturing transformation volume of different shale wells is obtained.

[0040] S102: Determine a scheme for performing hydraulic fracturing transformation on the target shale well based on the pressure transformation volumes of different shale wells.

[0041] In this embodiment, a shale well with the largest fracturing transformation volume is selected from the fracturing transformation volumes of different shale wells, and the fracturing construction pumping parameters and field geological parameters of the well are obtained as the fracturing construction pumping parameters and field geological parameters of the target shale well, so as to obtain a fracturing transformation plan for the target shale well.

[0042] S103: During the well soaking stage, the full-well imbibition energy enhancement volume of other different shale wells in the same area is obtained.

[0043] Specifically, during the shut-in stage, the bottom hole flow pressure data of other shale wells in the same area are obtained, and a flow characteristic curve is established based on the bottom hole flow pressure data; based on the flow characteristic curve, the shut-in pressure drop is divided into multiple flow stages; based on the flow stages, a quasi-steady-state flow mathematical model for fracture reservoir control is established; based on the quasi-steady-state flow mathematical model for fracture reservoir control, the effective volume of the main fractures in the entire well section and the effective volume of the secondary fractures in the entire well section are obtained; based on the effective volume of the main fractures in the entire well section and the effective volume of the secondary fractures in the entire well section, the full-well imbibition energy enhancement volume of each shale well in other shale wells is obtained.

[0044] Specifically, step 103 includes:

[0045] S1031: Acquire bottom hole flow pressure data during the well shut-in period, and draw a flow characteristic curve according to the bottom hole flow pressure data, wherein the characteristic curve includes a pressure drop curve and a pressure drop derivative curve.

[0046] S1032: dividing the shut-in pressure drop into nine flow stages according to the pressure drop curve and the pressure drop derivative curve, wherein the nine flow stages include four flow stages under the control of fractures at the end of the well section, four flow stages under the control of fractures in the entire well section, and a flow stage under matrix control;

[0047] refer to Figure 2 , Figure 2Schematic diagram of the pressure drop curve and pressure drop derivative curve provided in the embodiment of the present application. The fracturing cracks of the shale reservoir in this embodiment belong to Figure 2 The curve of "weak terminal connectivity + large secondary fracture scale" in the figure.

[0048] Among them, the four flow stages under the control of the final fracture include: the first stage ( Figure 2 ①), the wellbore continuous flow control stage, its pressure drop curve and pressure drop derivative curve coincide with each other and the slope is 1; the second stage ( Figure 2 ②), the end extension stage, the slope of the pressure drop derivative curve is 0; the third stage ( Figure 2 ③), the linear stage before closure, the slope of the pressure drop derivative curve is 1 / 2; the fourth stage ( Figure 2 ④), the crack closure control stage, the slope of the pressure drop derivative curve is greater than 1 / 2;

[0049] Among them, the four flow stages under the control of fractures in the whole well section include: the fifth stage ( Figure 2 ⑤), the last section-front section connected control stage, the curve of the pressure drop derivative presents a negative slope; the sixth stage ( Figure 2 ⑥), the main fracture reservoir stage, the pressure drop derivative curve presents a positive slope; the seventh stage ( Figure 2 In the middle (7), the crossflow control stage between the primary and secondary seams, the pressure drop derivative curve shows a negative slope; in the eighth stage ( Figure 2 Middle ⑧), secondary fracture reservoir stage, the curve of pressure drop derivative presents a positive slope;

[0050] Among them, the flow stages under matrix control are: the ninth stage ( Figure 2 In (9), the matrix flow control stage, the pressure drop derivative curve presents a negative slope until the pressure drop is zero.

[0051] S1033: Establish a pseudo-steady-state flow mathematical model for primary and secondary fracture reservoir control:

[0052] Main Crack:

[0053]

[0054] Secondary cracks:

[0055]

[0056] in

[0057] In the formula, p i is the initial formation pressure, MPa; p w is the bottom hole pressure, MPa; q m is the flow rate from the fracture to the matrix during the well soaking period, obtained by simulating the well soaking number based on the law of the imbibition experiment, m3 / d;Q m is the cumulative flow rate from fractures to matrix during well soaking, m 3 ; B w is the fracturing fluid volume coefficient, m 3 / m 3 ; V ehf The effective fracture volume of the main fracture, m 3 ; C hf Main crack compression coefficient, MPa -1 ; is the fracture porosity, a decimal; k f is the fracture permeability, mD; μ f is the fracturing fluid viscosity, mPa·s; L f Main crack half length; C t is the rock compression coefficient, MPa -1 ; V esf is the effective fracture volume of the secondary fracture, m 3 ; C sf is the secondary crack compression coefficient, MPa -1 ; C f is the comprehensive compression coefficient of cracks;

[0058] S1034: Perform numerical simulation using reservoir simulation software to obtain the crossflow rate q from the fracture to the matrix during the well shut-in period m and the cumulative crossflow rate from fractures to matrix during well shut-in period Q m ; Through the crack conductivity test, the main crack compression coefficient C is obtained hf and the secondary crack compression coefficient C sf ; Obtain the fracturing fluid volume coefficient B by querying oil field data w ;

[0059] S1035: When the bottom hole flowing pressure data during the soaking period is in the sixth stage, the pressure drop data in the sixth stage is used to draw a characteristic curve of standardized pressure and material balance time in a rectangular coordinate system, where the standardized pressure is (p i -p w ) / q m , material balance time is Q m / q m ; Get the slope value m of the characteristic curve f ;

[0060] S1036: According to the mathematical model of pseudo-steady-state flow controlled by the main fracture reservoir, we can obtain Import known C hf , and the effective volume V of the main fracture in the whole well section is obtained ehf for:

[0061]

[0062] S1037: When the bottom hole flowing pressure data during the soaking period is in the eighth stage, the pressure drop data in the eighth stage is used to draw a characteristic curve of standardized pressure and material balance time in a rectangular coordinate system, where the standardized pressure is (p i -p w ) / q m , material balance time is Q m / q m ; Get the slope value m of the characteristic curve F ;

[0063] S1038: Based on the pseudo-steady-state flow mathematical model controlled by secondary fracture reservoir, we obtain Import known C sf , the effective volume of the secondary crack V is obtained esf for:

[0064]

[0065] S1039: The effective volume of the main fractures in the entire well section V ehf And the effective volume of secondary crack V is obtained esf Add them together to get the total effective fracture volume V of the entire well section after pressure ef , which is the energy enhancement volume of the whole well.

[0066] S104: Determine the optimal soaking condition of the target shale well based on the full-well imbibition energy enhancement volume of different shale wells.

[0067] In this embodiment, a shale well with the largest whole-well imbibition energy enhancement volume is selected from the fracturing transformation volumes of different shale wells, and the shut-in time of the well is obtained as the optimal shut-in time of the target shale well.

[0068] S105: During the flowback stage, the oil production contribution matrix pore volume of other different shale wells in the same area is obtained.

[0069] Specifically, during the flowback stage, the bottom hole pressure data of other shale wells in the same area during the flowback period are obtained, and the double logarithmic curve of standardized pressure and material balance time, i.e., RNP curve, is drawn using the bottom hole pressure data; the cumulative oil production N is calculated based on the RNP curve. ps , cumulative water production W ps ; Based on the assumed fracture control water volume N and fracture control oil volume W, calculate the average pressure in the fracture control system at different times According to the average pressure in the fracture control system at different times, the water-phase pseudo-pressure difference at each moment is calculated, and the curves of the standardized production of water and oil phases and the curves of the standardized cumulative production are drawn; using the curves, the water reserves W in the fracture control effective volume and the crude oil reserves N in the fracture control effective volume are iteratively calculated; according to the water and oil reserves in the fracture control effective volume, the matrix pore volume contributing to the oil production of each shale well in other shale wells is calculated.

[0070] Specifically, step 105 specifically includes:

[0071] The step 105 specifically includes:

[0072] S1051: Acquire the bottom hole pressure data during the flowback period, and use the bottom hole pressure data to draw a double logarithmic curve of standardized pressure and material balance time, that is, an RNP curve; wherein the RNP curve calculation formula is:

[0073]

[0074] t MB =Q x / q x

[0075] Where RNP is the normalized pressure; x is the water phase w or the oil phase o; P fi - Average pressure in initial crack, MPa; P wf - Bottom hole pressure, MPa; q x -Water or oil phase production rate, m 3 / d;t MB -Material balance time, d (day); Q x - Cumulative production of water or oil phase, m 3 Since the actual fracture pressure is difficult to obtain, the average fracture pressure at the initial stage of flowback is assumed to be similar to the bottom hole pressure on the first day of flowback, and P fi Equal to the bottom hole flow pressure P when the well is opened wfi ;

[0076] refer to Figure 3 , Figure 3 A schematic diagram of a double logarithmic curve of standardized pressure and material equilibrium time provided in an embodiment of the present application.

[0077] When a straight line segment with a slope of 1 appears on the RNP curve ( Figure 3 The oil phase flow rate q in the quasi-steady-state stage is intercepted at the end of the primary stage of the fracture and the initial moment of the quasi-steady-state stage of the fracture-controlled zone. o and water phase flow rate q w , and bottom hole pressure p wf ; The bottom hole pressure at the beginning of the quasi-steady state is determined as the average pressure p in the fracture control areai .

[0078] S1052: Obtain the sand addition volume V of the entire well through the pressure construction report p ; Obtain the water phase compressibility coefficient C through the high-pressure physical parameters of the formation fluid w , oil phase compressibility coefficient C o , initial volume coefficient of water phase B wi , initial volume coefficient of oil phase B oi , initial viscosity of crude oil μ oi , initial viscosity of water phase μ wi and relative permeability curve; Assuming the fracture-controlled effective volume water reserves W, assuming the fracture-controlled effective volume crude oil reserves N; according to step B, obtain the main fracture effective volume V ehf and the effective volume of secondary cracks V esf .

[0079] S1053: According to the oilfield data, the assumed fracture-controlled effective volume water reserve W and the assumed fracture-controlled effective volume crude oil reserve N are assigned reasonable values ​​of the fracture-controlled effective volume water reserve W and the fracture-controlled effective volume crude oil reserve N; and the average pressure in the fracture-controlled system at different times is calculated by the following formula:

[0080]

[0081]

[0082]

[0083] V mp =B wi W+B oi NV ehf -V esf

[0084]

[0085] In the formula, Average pressure in the seam control system; W ps is the return water volume; N ps V is the volume of produced crude oil; mp is the pore volume of fracture-controlled matrix; C hf C is the main crack compression coefficient; sf is the secondary crack compression coefficient; C m is the matrix pore compression coefficient; B w is the fracturing fluid volume coefficient, m 3 / m 3 ; B o is the crude oil volume coefficient, m 3 / m 3 ;pn is the support pressure in the crack; p c is the net closing pressure in the fracture; t is the number of days of well opening and flowback.

[0086] S1054: Average pressure of the system according to the slit control at each moment The water phase pseudo pressure difference (p pi,w -p pwf,w ), Oil phase pseudo pressure difference (p pi,o -p pwf,o ),

[0087]

[0088]

[0089]

[0090] In the formula, p pi,w is the initial pseudo pressure of water phase, MPa; p pwf,w is the simulated bottom hole flow pressure of water phase; is the pseudo average pressure in the water phase fracture control area; μ wi is the initial viscosity of the water phase; B wi is the initial volume coefficient of the water phase; μ w (p) is the viscosity of the water phase under pressure p; B w (p) is the volume coefficient of the water phase at pressure p; k rw (p) is the relative permeability of water phase under the pressure p in the fracture control area;

[0091]

[0092]

[0093]

[0094] Where: p pi,o is the initial pseudo pressure of the oil phase, MPa; p pwf,o is the simulated bottom hole flowing pressure of the oil phase; is the pseudo average pressure in the oil phase fracture control area; μ oi is the initial viscosity of the oil phase; B oi is the initial volume coefficient of the oil phase; μ o (p) is the viscosity of the oil phase at pressure p; B o (p) is the volume coefficient of the oil phase at pressure p; k ro (p) is the relative permeability of the oil phase under the pressure p in the fracture control area;

[0095] S1055: Draw a target curve with the curves of the standardized yield of the water phase and the oil phase as the vertical axis and the standardized cumulative yield of the water phase and the oil phase as the horizontal axis; wherein the curve of the standardized yield of the water phase is The curve of the standardized yield of the oil phase is The curve of the normalized cumulative yield of the aqueous phase is The curve of the normalized cumulative yield of the oil phase is Extend the straight line part of the target curve to intersect with the x-axis. The intersection point is the water reserve W in the effective volume of fracture control and the crude oil reserve N in the effective volume of fracture control.

[0096] S1056: Compare the water storage W in the fracture-controlled effective volume and the crude oil storage N in the fracture-controlled effective volume obtained in step SC5 with the water storage W in the fracture-controlled effective volume and the crude oil storage N in the fracture-controlled effective volume assumed in step 3. If the error condition is not met, the calculation result of step SC5 is used as the assumed condition of step SC3, and steps SC3-SC5 are calculated repeatedly until the water storage W in the fracture-controlled effective volume and the crude oil storage N in the fracture-controlled effective volume that meet the error condition are obtained.

[0097] S1057: Add the water reserves W in the fracture-controlled effective volume and the crude oil reserves N in the fracture-controlled effective volume to obtain the matrix pore volume V contributing to oil production. mp .

[0098] S106: Based on the matrix pore volumes contributing to oil production of different shale wells, determine the size of the blowdown nozzle and the flowback plan of the target shale well.

[0099] In this embodiment, a shale well with the largest matrix pore volume contributing to oil production is selected from among the matrix pore volumes contributing to oil production of different shale wells, and the blowdown nozzle size and flowback scheme of the well are obtained as the blowdown nozzle size and flowback scheme of the target shale well.

[0100] S107: During the well opening and production phase, obtain the recoverable reserves of other shale wells in the same area.

[0101] Specifically, in the well production stage, the well production output q and cumulative oil production N of other shale wells in the same area are obtained. p ; According to the production output q and the cumulative oil production N p , establish the production output q and cumulative oil production N p , find the coefficients a and m of the relationship; use the production volume q of the well and the cumulative oil production N p The coefficient of the relationship between the production output q and the production time t is obtained, and q1 and q are obtained. ∞ ; Calculate the recoverable reserves of each shale well within the specified lifespan of other shale wells.

[0102] Wherein, step D specifically comprises:

[0103] S1071: Obtain the production output q and cumulative oil production N of the well. p , and establish the production output q and cumulative oil production N p The relationship is:

[0104]

[0105] In the formula, t is the number of days of well opening and flowback, and a and m are coefficients;

[0106] Production (q / N p )—t double logarithmic curve graph, calculate the a and m values.

[0107] S1072: Taking the first day output of the decreasing phase as q1, fit the relationship between production output q and time t according to the following formula to obtain q ∞ :

[0108]

[0109] q=q1t(a,m)+q ∞

[0110] In the formula, q ∞ is the intercept of the straight line between q and t(a,m).

[0111] S1073: Using the formula in step SD2, predict the recoverable reserves of a single well in a specified period of time. The formula is as follows:

[0112] EUR=∑q

[0113] Where EUR is the recoverable reserves of a single well.

[0114] S108: Determine a production plan for the target shale well based on the recoverable reserves of the oil wells within the specified lifespan of different shale wells.

[0115] In this embodiment, a shale well with the largest single-well recoverable reserves is selected from the single-well recoverable reserves of different shale wells, and the well opening and production plan of the well is obtained as the well opening and production plan of the target shale well.

[0116] In summary, the embodiments of the present application provide a method for regulating the post-fracturing production system of a fracturing well throughout its life cycle. In the fracturing stage, the fracturing transformation volume of different shale wells is obtained; based on the pressure transformation volume of different shale wells, a fracturing transformation plan for a target shale well is determined; in the shut-in stage, the full-well imbibition energy enhancement volume of different shale wells is obtained; based on the full-well imbibition energy enhancement volume of different shale wells, the optimal shut-in condition of the target shale well is determined; in the flowback stage, the oil production contribution matrix pore volume of different shale wells is obtained; based on the oil production contribution matrix pore volume of different shale wells, the oil nozzle size and flowback plan of the target shale well are determined; in the well opening and production stage, the single-well recoverable reserves of different shale wells are obtained; based on the single-well recoverable reserves of the oil wells within the specified years of different shale wells, the production plan of the target shale well is determined. During the fracturing well construction process, the fracturing construction effect of the construction well is continuously evaluated, and the plans for the subsequent fracturing construction stage, well shut-in stage, flowback stage and well opening and production stage are continuously optimized and regulated according to the inversion parameters, achieving the technical effect of improving the ultimate recovery rate of a single well.

[0117] The following mainly describes a specific example of applying the above-mentioned method for controlling the post-fracture production system throughout the life cycle of a fractured well:

[0118] 1) During the fracturing stage, two wells, Y1 and Y2, were selected for construction pressure drop fitting. The horizontal section of the Y1 well was evenly divided into 39 sections, each of which was mainly composed of 8 clusters. The total amount of sand entering the well was 7164m 3 The total amount of fluid entering the well is 72482m 3 The horizontal section of the Y2 well is evenly divided into 34 sections, each section is mainly composed of 6 clusters, and the total amount of sand entering the well is 6221m 3 The total amount of fluid entering the well is 64750m 3 The fracturing construction parameters of the two wells Y1 and Y2 were obtained, and numerical simulation was performed using unconventional shale reservoir simulation software to simulate the formation fracture morphology. The fracturing transformation volumes of the two wells Y1 and Y2 were obtained, which were: the fracturing transformation volume SRV of the Y1 well was 51462m 3 The SRV of the fracturing transformation volume of Well Y2 is 44677m 3 .

[0119] Subsequently, for the target wells, the fracturing construction pumping parameters of Well Y1 and the on-site geological parameters were used as the fracturing transformation plan.

[0120] 2) During the well shut-in stage, the bottom hole flow pressure data of Y1 (well shut-in for 60 days) and Y2 (well shut-in for 30 days) were counted, the pressure drop and the double logarithm of the pressure drop derivative were analyzed, and the double logarithm curves of the pressure drop and its natural logarithm derivative during the well shut-in period of Y1 and Y2 were drawn. The full well imbibition energy volume V of Y1 was calculated. ef =52236m 3, the full well imbibition energy volume V of Y2 is calculated ef =50894m 3 .

[0121] For the target wells, the full-well imbibition energy enhancement volume of Well Y1 is larger, so the shut-in time of the target well can be selected as 60 days.

[0122] 3) In the flowback stage, the flowback system of Y1 well was collected: after the well was opened, 2.5mm-3mm nozzle was used for blowback. Daily liquid production was 67.5m 3 . Y2 well flowback system: After the Y2 well is opened, a 3mm-4mm nozzle is used for blowback. Daily liquid production is 90m 3 By statistically analyzing the flowback data, the oil production contribution fracture volume of wells Y1 and Y2 was calculated. After calculation, the oil production contribution matrix pore volume (DRV) of well Y1 is 224.9×10 4 m 3 ; The oil production contribution matrix pore volume (DRV) of Well Y2 is 200.38×10 4 m 3 .

[0123] For the target wells, the oil production contribution of Well Y1 is larger. Therefore, the flowback system of the target well can choose 2.5mm-3mm oil nozzle for blowback, with a daily liquid production of 67.5m 3 .

[0124] 4) During the well opening and production stage, the production system of well Y1 is collected: well Y1 has been in long-term self-flowing production, and when the wellhead pressure reaches 3MPa, it is converted from self-flowing production to pumping production. Production system of well Y2: well Y2 has been in long-term self-flowing production, and when the wellhead pressure drops to 0MPa and self-flowing production is no longer possible, it is converted to pumping production. By statistically analyzing the long-term production data, the recoverable reserves of each well of wells Y1 and Y2 are calculated. After calculation, the recoverable reserves of well Y1 = 6.14×10 4 Tons; the recoverable reserves of Y2 well = 3.77 × 10 4 ton.

[0125] For the target wells, the single well recoverable reserves of Y1 well are larger. Therefore, the target wells can be switched from self-flowing oil production to pumping oil production when the wellhead pressure is 3MPa.

[0126] Corresponding to the method for controlling the post-fracturing production system of a fracturing well throughout its life cycle in the above embodiment, Figure 4 A structural block diagram of a post-fracture production system control device for a fracturing well during its entire life cycle provided in an embodiment of the present application. For ease of explanation, only the parts related to the embodiment of the present application are shown.

[0127] Reference Figure 4The post-fracturing production system control device for the entire life cycle of the fracturing well includes: a fracturing processing module 201, a shut-in processing module 202, a flowback processing module 203 and a production processing module 204.

[0128] The fracturing processing module 201 is used to obtain the fracturing construction parameters of other shale wells in the same area during the fracturing stage, use unconventional shale reservoir simulation software to perform numerical simulation to simulate the formation fracture morphology, and obtain the fracturing transformation volume of different shale wells; based on the pressure transformation volume of different shale wells, a fracturing transformation plan for the target shale well is carried out;

[0129] Well shut-in processing module 202 is used to obtain the full-well imbibition energy enhancement volume of other different shale wells in the same area during the well shut-in stage; based on the full-well imbibition energy enhancement volume of different shale wells, determine the optimal well shut-in condition of the target shale well;

[0130] The flowback processing module 203 is used to obtain the oil production contribution matrix pore volume of other different shale wells in the same area during the flowback stage; based on the oil production contribution matrix pore volume of different shale wells, determine the oil nozzle size and flowback plan of the target shale well;

[0131] The production processing module 204 is used to obtain the recoverable reserves of other shale wells in the same area during the well opening and production stage; based on the recoverable reserves of oil wells under the specified life of different shale wells, determine the production plan of the target shale well.

[0132] In one possible design, the shut-in processing module 202 is specifically used to obtain bottom hole flow pressure data of other shale wells in the same area during the shut-in stage, and establish a flow characteristic curve based on the bottom hole flow pressure data; based on the flow characteristic curve; divide the shut-in pressure drop into multiple flow stages; based on the flow stages, establish a quasi-steady-state flow mathematical model for fracture reservoir control; according to the quasi-steady-state flow mathematical model for fracture reservoir control, obtain the effective volume of main fractures in the entire well section and the effective volume of secondary fractures in the entire well section; according to the effective volume of main fractures in the entire well section and the effective volume of secondary fractures in the entire well section, obtain the full-well imbibition energy enhancement volume of each shale well in other shale wells.

[0133] In a possible design, the flowback processing module 203 is specifically used to obtain the bottom hole pressure data of other shale wells in the same area during the flowback period during the flowback stage, and use the bottom hole pressure data to draw a double logarithmic curve of standardized pressure and material balance time, that is, an RNP curve; calculate the cumulative oil production N according to the RNP curve ps , cumulative water production W ps ; Based on the assumed fracture control water volume N and fracture control oil volume W, calculate the average pressure in the fracture control system at different times According to the average pressure in the fracture control system at different times, the water-phase pseudo-pressure difference at each moment is calculated, and the curves of the standardized production of water and oil phases and the curves of the standardized cumulative production are drawn; using the curves, the water reserves W in the fracture control effective volume and the crude oil reserves N in the fracture control effective volume are iteratively calculated; according to the water and oil reserves in the fracture control effective volume, the matrix pore volume contributing to the oil production of each shale well in other shale wells is calculated.

[0134] In a possible design, the production processing module 204 is specifically used to obtain the production output q and cumulative oil production N of other shale wells in the same area during the well production phase. p ; According to the production output q and the cumulative oil production N p , establish the production output q and cumulative oil production N p , find the coefficients a and m of the relationship; use the production volume q of the well and the cumulative oil production N p The coefficient of the relationship between the production output q and the production time t is obtained, and q1 and q are obtained. ∞ ; Calculate the recoverable reserves of each shale well within the specified lifespan of other shale wells.

[0135] The device provided in this embodiment can be used to execute the technical solution of the above method embodiment. Its implementation principle and technical effect are similar, and this embodiment will not be repeated here.

[0136] Figure 5 The hardware structure diagram of the computer provided in the embodiment of the present application is shown in FIG. Figure 5 As shown, the computer device of this embodiment includes: a processor 301 and a memory 302;

[0137] Memory 302, used to store computer-executable instructions;

[0138] The processor 301 is used to execute the computer-executable instructions stored in the memory to implement the various steps executed by the computer device in the above embodiment. For details, please refer to the relevant description in the above method embodiment.

[0139] Optionally, the memory 302 may be independent or integrated with the processor 301 .

[0140] When the memory 302 is independently provided, the computer further includes a bus 303 for connecting the memory 302 and the processor 301 .

[0141] An embodiment of the present application also provides a computer-readable storage medium, in which computer-executable instructions are stored. When a processor executes the computer-executable instructions, the method for controlling the post-fracturing production system of a fracturing well throughout its life cycle as described above is implemented.

[0142] An embodiment of the present application also provides a computer program product, including a computer program. When the computer program is executed by a processor, the method for controlling the post-fracturing production system of a fracturing well throughout its life cycle as described above is implemented.

[0143] In the several embodiments provided in the present application, it should be understood that the disclosed devices and methods can be implemented in other ways. For example, the device embodiments described above are only schematic. For example, the division of the modules is only a logical function division. There may be other division methods in actual implementation, such as multiple modules can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the mutual coupling or direct coupling or communication connection shown or discussed can be an indirect coupling or communication connection through some interfaces, devices or modules, which can be electrical, mechanical or other forms.

[0144] The modules described as separate components may or may not be physically separated, and the components shown as modules may or may not be physical units, that is, they may be located in one place or distributed on multiple network units. Some or all of the modules may be selected according to actual needs to implement the solution of this embodiment.

[0145] In addition, each functional module in each embodiment of the present application can be integrated into one processing unit, or each module can exist physically separately, or two or more modules can be integrated into one unit. The above-mentioned module-composed unit can be implemented in the form of hardware or in the form of hardware plus software functional units.

[0146] The above-mentioned integrated module implemented in the form of a software function module can be stored in a computer-readable storage medium. The above-mentioned software function module is stored in a storage medium, including a number of instructions for causing a computer device (which can be a personal computer, a server, or a network device, etc.) or a processor to perform some steps of the method described in each embodiment of the present application.

[0147] It should be understood that the processor may be a central processing unit (CPU), or other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), etc. A general-purpose processor may be a microprocessor or any conventional processor. The steps of the method disclosed in the invention may be directly implemented as being executed by a hardware processor, or may be implemented by a combination of hardware and software modules in the processor.

[0148] The memory may include a high-speed RAM memory, and may also include a non-volatile storage NVM, such as at least one disk memory, and may also be a USB flash drive, a mobile hard disk, a read-only memory, a magnetic disk or an optical disk, etc.

[0149] The bus may be an Industry Standard Architecture (ISA) bus, a Peripheral Component Interconnect (PCI) bus, or an Extended Industry Standard Architecture (EISA) bus, etc. The bus may be divided into an address bus, a data bus, a control bus, etc. For ease of representation, the bus in the drawings of the present application is not limited to only one bus or one type of bus.

[0150] The above storage medium can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as static random access memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic memory, flash memory, magnetic disk or optical disk. The storage medium can be any available medium that can be accessed by a general or special purpose computer.

[0151] An exemplary storage medium is coupled to a processor so that the processor can read information from the storage medium and write information to the storage medium. Of course, the storage medium can also be a component of the processor. The processor and the storage medium can be located in an application specific integrated circuit (ASIC). Of course, the processor and the storage medium can also exist as discrete components in an electronic device or a main control device.

[0152] Those skilled in the art can understand that all or part of the steps of implementing the above-mentioned method embodiments can be completed by hardware related to program instructions. The aforementioned program can be stored in a computer-readable storage medium. When the program is executed, the steps of the above-mentioned method embodiments are executed; and the aforementioned storage medium includes: ROM, RAM, disk or optical disk and other media that can store program codes.

[0153] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present application, rather than to limit it. Although the present application 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 replace some or all of the technical features therein with equivalents. However, these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the embodiments of the present application.

Claims

1. A method for regulating the post-fracturing production system of a fracturing well during its entire life cycle, characterized in that: The method is applied to any target shale well, comprising: During the fracturing stage, the fracturing construction parameters of other shale wells in the same area were obtained, and numerical simulation was performed using unconventional shale reservoir simulation software to simulate the formation fracture morphology and obtain the fracturing transformation volume of different shale wells; Determining a scheme for fracturing the target shale well based on the pressure transformation volumes of different shale wells; In the well shut-in stage, the full-well imbibition energy-increasing volumes of other different shale wells in the same area are obtained; based on the full-well imbibition energy-increasing volumes of different shale wells, the optimal well shut-in conditions of the target shale well are determined; In the flowback stage, the matrix pore volume contributing to oil production of other different shale wells in the same area is obtained; Determine the size of the oil nozzle and the flowback scheme of the target shale well based on the matrix pore volume contributed by the oil production of different shale wells; During the well production phase, obtain the recoverable reserves of other shale wells in the same area; Determine the production plan of the target shale well based on the recoverable reserves of the oil wells under the specified life of different shale wells; In the well soaking stage, the full-well imbibition energy enhancement volume of other different shale wells in the same area is obtained, including: In the well shut-in stage, the bottom hole flow pressure data of other shale wells in the same area are obtained, and a flow characteristic curve is established according to the bottom hole flow pressure data; based on the flow characteristic curve, the well shut-in pressure drop is divided into multiple flow stages; based on the flow stages, a pseudo-steady-state flow mathematical model for fracture reservoir control is established; according to the pseudo-steady-state flow mathematical model for fracture reservoir control, the effective volume of the main fractures of the whole well section and the effective volume of the secondary fractures of the whole well section are obtained; according to the effective volume of the main fractures of the whole well section and the effective volume of the secondary fractures of the whole well section, the full-well imbibition energy enhancement volume of each shale well of other shale wells is obtained; according to the effective volume of the main fractures of the whole well section and the effective volume of the secondary fractures of the whole well section, the full-well imbibition energy enhancement volume of each shale well of other shale wells is obtained, including: Adding the effective volume of the main fractures of the whole well section and the effective volume of the secondary fractures of the whole well section to obtain the total effective fracture volume of the whole well section after compression, and determining the total effective fracture volume of the whole well section after compression as the whole well imbibition energy enhancement volume; In the flowback stage, the oil production contribution matrix pore volume of other different shale wells in the same area is obtained, including: In the flowback stage, the bottom hole pressure data of other shale wells in the same area during the flowback period are obtained, and the double logarithmic curve of standardized pressure and material balance time, i.e., RNP curve, is drawn using the bottom hole pressure data; the cumulative oil production N is calculated based on the RNP curve. ps , cumulative water production W ps ; Based on the assumed fracture control water volume N and fracture control oil volume W, calculate the average pressure in the fracture control system at different times According to the average pressure in the fracture control system at different times, the water-phase pseudo pressure difference at each moment is calculated, and the curves of the standardized production of water and oil phases and the standardized cumulative production curve are drawn; using the curves, the water reserves W in the fracture control effective volume and the crude oil reserves N in the fracture control effective volume are iteratively calculated; according to the water and oil reserves in the fracture control effective volume, the matrix pore volume contributing to the oil production of each shale well in other shale wells is calculated; The oil production contribution matrix pore volume of each shale well calculated based on the water-oil reserves in the fracture-controlled effective volume includes: The water reserve in the fracture-controlled effective volume and the crude oil reserve in the fracture-controlled effective volume are added together to obtain the matrix pore volume contributing to oil production.

2. The method according to claim 1, characterized in that During the well opening and production phase, the recoverable reserves of other shale wells in the same area are obtained, including: In the well production stage, obtain the well production output q and cumulative oil production N of other shale wells in the same area p ; According to the production output q and the cumulative oil production N p , establish the production output q and cumulative oil production N p , find the coefficients a and m of the relationship; use the production volume q of the well and the cumulative oil production N p The coefficient of the relationship between the production output q and the production time t is obtained, and q1 and q are obtained. ∞ ; Calculate the recoverable reserves of each shale well under the specified lifespan of other shale wells; q1 is the first day production, q ∞ It is the intercept in the relationship between the production output q and the production time t.

3. The method according to claim 1 or 2, characterized in that: The fracturing construction parameters include fracturing construction pumping parameters and on-site geological parameters; The fracturing construction pumping parameters include: fracturing fluid viscosity, density and type; the proportion of different types of fracturing fluid; injection time and injection volume of different types of fracturing fluid; proppant density, size and type; injection volume of proppant at different stages; stopping the pump after the pumping is completed, and obtaining the construction pressure drop data through on-site pressure statistics; The on-site geological parameters include: Young's modulus and Poisson's ratio of the target formation obtained from uniaxial compression tests.

4. A post-fracturing production system control device for a fracturing well during its entire life cycle, characterized in that: The device is applied to any target shale well, and comprises: The fracturing processing module is used to obtain the fracturing construction parameters of other shale wells in the same area during the fracturing stage, and use unconventional shale reservoir simulation software to perform numerical simulation to simulate the formation fracture morphology and obtain the fracturing transformation volume of different shale wells; based on the pressure transformation volume of different shale wells, determine the fracturing transformation plan for the target shale well; The well shut-in processing module is used to obtain the full-well imbibition energy enhancement volume of other different shale wells in the same area during the well shut-in stage; based on the full-well imbibition energy enhancement volume of different shale wells, determine the optimal well shut-in condition of the target shale well; the flowback processing module is used to obtain the oil production contribution matrix pore volume of other different shale wells in the same area during the flowback stage; based on the oil production contribution matrix pore volume of different shale wells, determine the oil nozzle size and flowback plan of the target shale well; The production processing module is used to obtain the recoverable reserves of other shale wells in the same area during the well opening and production stage; determine the production plan of the target shale well based on the recoverable reserves of oil wells in the specified years of different shale wells; the shut-in processing module is specifically used to obtain the bottom hole flow pressure data of other shale wells in the same area during the shut-in stage, establish a flow characteristic curve based on the bottom hole flow pressure data; divide the shut-in pressure drop into multiple flow stages based on the flow characteristic curve; and establish a pseudo-steady-state flow mathematical model for fracture reservoir control based on the flow stage; According to the pseudo-steady-state flow mathematical model for fracture reservoir control, the effective volume of the main fractures of the whole well section and the effective volume of the secondary fractures of the whole well section are obtained; according to the effective volume of the main fractures of the whole well section and the effective volume of the secondary fractures of the whole well section, the full-well imbibition energy enhancement volume of each shale well of other shale wells is obtained; the well soaking treatment module is specifically used to add the effective volume of the main fractures of the whole well section and the effective volume of the secondary fractures of the whole well section to obtain the total effective fracture volume of the whole well section after pressure, and the total effective fracture volume of the whole well section after pressure is determined as the full-well imbibition energy enhancement volume; The flowback processing module is specifically used to obtain the bottom hole pressure data of other shale wells in the same area during the flowback stage, and use the bottom hole pressure data to draw a double logarithmic curve of standardized pressure and material balance time, that is, RNP curve; calculate the cumulative oil production N according to the RNP curve ps , cumulative water production W ps ; Based on the assumed fracture control water volume N and fracture control oil volume W, calculate the average pressure in the fracture control system at different times According to the average pressure in the fracture control system at different times, the water-phase pseudo pressure difference at each moment is calculated, and the curves of the standardized production of water and oil phases and the standardized cumulative production curve are drawn; using the curves, the water reserves W in the fracture control effective volume and the crude oil reserves N in the fracture control effective volume are iteratively calculated; according to the water and oil reserves in the fracture control effective volume, the matrix pore volume contributing to the oil production of each shale well in other shale wells is calculated; The flowback processing module is specifically used to add the water reserves in the fracture-controlled effective volume and the crude oil reserves in the fracture-controlled effective volume to obtain the oil-producing contributing matrix pore volume.

5. A computer device, characterized in that: include: at least one processor and memory; The memory stores computer-executable instructions; The at least one processor executes the computer-executable instructions stored in the memory, so that the at least one processor executes the post-fracturing production system control processing method for the entire life cycle of a fracturing well as described in any one of claims 1 to 3.

6. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores computer-executable instructions. When the processor executes the computer-executable instructions, the method for controlling the post-fracturing production system of a fracturing well throughout its life cycle as described in any one of claims 1 to 3 is implemented.

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