Full life cycle fracture volume evaluation processing method and device

Abstract

The present application provides a method and device for evaluating and processing the volume of fractures during the whole life cycle, the method comprising: obtaining the fracturing construction pumping parameters and the field geological parameters of the on-site volume fracturing construction, simulating the actual formation fracture expansion morphology, and obtaining the fracturing transformation volume of the whole horizontal well section; obtaining the bottom hole flow pressure data during the well shut-in period, drawing the flow characteristic curve according to the bottom hole flow pressure data, and obtaining the whole well permeation energy enhancement volume according to the effective volume of the main fracture of the whole well section and the effective volume of the secondary fracture of the whole well section; obtaining the bottom hole pressure data during the backflow period, using the bottom hole pressure data to draw the double logarithmic curve of the standardized pressure and the material balance time, and calculating the matrix pore volume contributing to oil production; obtaining the production output and the cumulative oil production of the well opening, and calculating the recoverable reserves of the single well of the oil well under the specified period of time. It is possible to comprehensively evaluate the fracture volume during the whole life cycle, and realize the rapid evaluation of the fracturing construction effect of the whole life cycle of the well section to be evaluated.

Description

Technical Field

[0001] The present application relates to the technical field of oil and gas reservoir exploration and development, and in particular to a method and device for evaluating and processing the volume of a full life cycle hydraulic fracture. Background Art

[0002] Shale reservoirs are a type of unconventional oil and gas reservoirs that require large-scale volume fracturing to achieve industrial production capacity. After volume fracturing of shale reservoirs, the fracturing effect needs to be evaluated based on the geological properties of the fracturing layer, the fracturing technology and construction scale of the well, and the post-fracturing well shut-in and flowback conditions. Among them, the focus of the fracturing effect evaluation is on the evaluation of fracture volume, including the fracture volume (SRV) of the fracturing transformation, the full-well permeability enhancement volume (IRV), the matrix pore volume (DRV) contributing to oil production, and the evaluation of the recoverable reserves (EUR) of a single well.

[0003] At present, the existing fracture volume evaluation methods mainly include forward physical simulation evaluation and numerical simulation evaluation, as well as the inversion method of pressure drop test interpretation to evaluate the fracturing effect of oil and gas layers. However, the existing fracture volume evaluation methods are not suitable for the evaluation of fracturing effect of the entire horizontal well section of shale reservoirs.

[0004] The entire horizontal well section of the shale reservoir is usually subjected to segmented multi-cluster fracturing, and the fracture extension patterns are diverse and the fracture network expansion behavior is complex, resulting in the use of pressure drop curves showing the characteristics of "multiple types, multiple changes, and multiple well sections". The pump-stop pressure drop monitoring time after fracturing construction generally needs to last from several hours to more than ten hours. However, due to the relatively dense shale reservoir, the fractures have not yet closed within a short monitoring time, and the fracture geometry cannot be calculated, which cannot meet the requirements for normal fracturing effect evaluation after the fractures are closed. Therefore, a full-life cycle fracturing fracture volume evaluation method is urgently needed, which comprehensively evaluates the fracture volume of the fracturing well during the full cycle of fracturing construction pressure drop, well shut-in pressure drop, backflow pressure drop, and dynamic production. Summary of the invention

[0005] The embodiments of the present application provide a method and device for evaluating and processing the volume of hydraulic fractures during the entire life cycle. By comprehensively evaluating the fracture volume of the hydraulic fracture well during the entire cycle of hydraulic fracture construction pressure drop, well shut-in pressure drop, flowback pressure drop and dynamic production, a rapid evaluation of the hydraulic fracture construction effect of the well section to be evaluated during the entire life cycle is achieved.

[0006] In a first aspect, an embodiment of the present invention provides a method for evaluating and processing a hydraulic fracture volume during a full life cycle, comprising:

[0007] Step A: Obtain the fracturing pumping parameters and on-site geological parameters of the on-site volume fracturing construction, and input the fracturing pumping parameters and on-site geological parameters into reservoir simulation software for numerical simulation. During the numerical simulation process, fit the fracturing construction pressure drop, simulate the actual formation fracture propagation morphology, and obtain the fracturing reconstruction volume of the entire horizontal well section;

[0008] Step B: Obtain the bottom-hole flowing pressure data during the shut-in period, draw the flow characteristic curve based on the bottom-hole flowing pressure data, and divide the shut-in pressure drop into multiple flow stages according to the flow characteristic curve; Based on the flow stage, establish a pseudo-steady state flow mathematical model for fracture storage control; According to the pseudo-steady state flow mathematical model for fracture storage control, obtain 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; According to 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, obtain the imbibition energy-increasing volume of the entire well;

[0009] Step C: Obtain the bottom-hole pressure data during the flowback period, and draw a double logarithmic curve of the normalized pressure and the material balance time, i.e., the RNP curve; Calculate the cumulative oil production N ps and the cumulative water production W ps according to the RNP curve; According to the assumed water control volume N and oil control volume W in the fracture, 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, calculate the water-phase and oil-phase pseudo-pressure differences at each moment, and draw the curves of the normalized production and the normalized cumulative production of water and oil phases; Use the curves to iteratively calculate and obtain the water storage W in the fracture control effective volume and the crude oil storage N in the fracture control effective volume; According to the water and oil storage in the fracture control effective volume, calculate the matrix pore volume contributing to oil production;

[0010] Step D: Obtain the production rate q and the cumulative oil production N of the open well production p ; According to the production rate q and the cumulative oil production N of the open well production p , establish a relationship between the production rate q and the cumulative oil production N p of the open well production, and obtain the coefficients a and m of the relationship; Use the coefficients of the relationship between the production rate q and the cumulative oil production N p of the open well production, and obtain the relationship between the production rate q and the production time t, and obtain q 1 and q ∞ ; Calculate the recoverable reserve per well of the oil well under the specified years.

[0011] In a second aspect, an embodiment of the present invention provides a device for evaluating and processing the volume of a fracturing fracture during the entire life cycle, including:

[0012] The fracturing reconstruction fracture volume processing module is used to obtain the fracturing construction pumping parameters and on-site geological parameters of the on-site volume fracturing construction, and input the fracturing construction pumping parameters and on-site geological parameters into reservoir simulation software for numerical simulation. During the numerical simulation process, the pressure drop during fracturing construction is fitted, the actual formation fracture propagation morphology is simulated, and the fracturing reconstruction volume of the entire horizontal well section is obtained;

[0013] The whole-well imbibition energy-increasing volume processing module is used to obtain the bottom-hole flowing pressure data during the shut-in period, draw the flow characteristic curve according to the bottom-hole flowing pressure data, and divide the shut-in pressure drop into multiple flow stages based on the flow characteristic curve; based on the flow stage, establish a pseudo-steady-state flow mathematical model for fracture storage control; according to the pseudo-steady-state flow mathematical model for fracture storage control, obtain the effective volume of the main fractures in the whole well section and the effective volume of the secondary fractures in the whole well section; according to the effective volume of the main fractures in the whole well section and the effective volume of the secondary fractures in the whole well section, obtain the whole-well imbibition energy-increasing volume;

[0014] The matrix pore volume processing module for oil production contribution is used to obtain the bottom-hole pressure data during the flowback period, draw a double logarithmic curve of the normalized pressure and the material balance time, that is, the RNP curve; calculate the cumulative oil production N ps and the cumulative water production W ps according to the RNP curve; calculate the average pressure in the fracture control system at different times according to the assumed fracture-controlled water volume N and fracture-controlled oil volume W According to the average pressure in the fracture control system at different times, calculate the water-oil phase pseudo-pressure difference at each moment, and draw the curves of the normalized production and the normalized cumulative production of the water and oil phases; use the curves to iteratively calculate and obtain the water storage W in the fracture control effective volume and the crude oil storage N in the fracture control effective volume; calculate the matrix pore volume for oil production contribution according to the water and oil storage in the fracture control effective volume;

[0015] The single-well recoverable reserve processing module is used to obtain the open-well production rate q and the cumulative oil production N p ; according to the open-well production rate q and the cumulative oil production N p , establish a relationship between the open-well production rate q and the cumulative oil production N p , and obtain the coefficients a and m of the relationship; use the coefficients of the relationship between the open-well production rate q and the cumulative oil production N p , and obtain the relationship between the open-well production rate q and the production time t, and obtain q 1 and q ∞ ; calculate the single-well recoverable reserve of the oil well under the specified years.

[0016] In a third aspect, an embodiment of the present invention provides a computer device, including: at least one processor and a memory;

[0017] The memory stores computer-executable instructions;

[0018] The at least one processor executes the computer-executable instructions stored in the memory, so that the at least one processor executes the full-life-cycle fracturing fracture volume evaluation processing method described in the first aspect above and various possible designs of the first aspect.

[0019] In a fourth aspect, an embodiment of the present invention provides a computer-readable storage medium, in which computer-executable instructions are stored. When a processor executes the computer-executable instructions, the full-life-cycle fracturing fracture volume evaluation processing method described in the first aspect above and various possible designs of the first aspect is implemented.

[0020] The full-life-cycle fracturing fracture volume evaluation processing method and device provided by the embodiments of the present invention comprehensively evaluate the fracture volume during the full life cycle of the fracturing well during the fracturing construction pressure drop, shut-in pressure drop, flowback pressure drop, and dynamic production process, and realize the rapid evaluation of the fracturing construction effect of the well section to be evaluated during the full life cycle. BRIEF DESCRIPTION OF THE DRAWINGS

[0021] In order to more clearly illustrate the technical solutions in the embodiments of the present application or the prior art, the following will briefly introduce the attached Figure 1 drawings required for use in the description of the embodiments or the prior art. Obviously, the drawings in the following description are some embodiments of the present application. For those of ordinary skill in the art, other drawings can be obtained based on these drawings without creative efforts.

[0022] Figure 1 It is a schematic flow chart of the full-life-cycle fracturing fracture volume evaluation processing method provided by the embodiments of the present invention;

[0023] Figure 2 It is a schematic diagram of the pressure drop curve and the pressure drop derivative curve provided by the embodiments of the present invention;

[0024] Figure 3 It is a schematic diagram of the double logarithmic curve of the normalized pressure and the material balance time provided by the embodiments of the present invention;

[0025] Figure 4 It is a schematic diagram simulating the actual formation fracture propagation morphology;

[0026] Figure 5 It is a schematic diagram of the pressure drop curve and the pressure drop derivative curve and curve fitting;

[0027] Figure 6 It is a double logarithmic curve graph of the normalized pressure and the material balance time in the flow stage ⑥ provided by the embodiments of the present invention;

[0028] Figure 7 It is the double logarithmic curve graph of the standardized pressure and the material balance time in the flowing stage ⑧ provided by the embodiment of the present invention;

[0029] Figure 8 It is the flowing material balance curve graph of the oil phase;

[0030] Figure 9 It is the flowing material balance curve graph of the water phase;

[0031] Figure 10 It is the double logarithmic curve graph of (q / Np)-t of Well X;

[0032] Figure 11 It is the relationship curve graph of q and t(a,m);

[0033] Figure 12 It is the structural block diagram of the full life cycle fracturing crack volume evaluation and processing device provided by the embodiment of the present invention;

[0034] Figure 13 It is the schematic diagram of the hardware structure of the computer device provided by the embodiment of the present invention. Specific Embodiments

[0035] To make the objectives, technical solutions and advantages of the embodiments of the present application clearer, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the accompanying drawings in the embodiments of the present application. Apparently, the described embodiments are some but not all of the embodiments of the present application. All other embodiments obtained by those of ordinary skill in the art based on the embodiments of the present application without making creative efforts shall fall within the protection scope of the present application.

[0036] First, the terms related to the present invention will be explained below.

[0037] Hydraulic fracturing: Hydraulic fracturing is an important engineering method in the application of unconventional oil and gas exploitation. This method can transform medium and low permeability oil and gas reservoirs to increase the production of oil and gas wells, and can efficiently recover unconventional oil and gas from low-permeability tight reservoirs. Hydraulic fracturing is to use a well pump to transport a large displacement of fracturing fluid into the formation. When the injected fracturing fluid reaches a certain level, the reservoir will be under high pressure and cracks will be generated. Then, continuously inject fracturing fluid into the reservoir, resulting in the continuous expansion of the cracks. To prevent the cracks from being squeezed and closed, fracturing fluid with proppant is then injected. On the one hand, it can keep the cracks existing and not closed due to pressure, and on the other hand, it can also make the cracks continue to extend. Finally, the fracturing fluid is recovered, and the proppant remains in the cracks, leaving multiple cracks, creating new fluid channels in the reservoir. The production of the oil and gas wells after fracturing will increase significantly. Therefore, it is of great significance to evaluate the fracturing effect in oil and gas exploration and development.

[0038] Embodiments of the present invention relate to hydraulic fracturing technology for unconventional oil and gas reservoirs. Specifically, a technology for evaluating the volume of fracturing fractures throughout the life cycle is provided. Embodiments of the present invention provide technical support for quickly evaluating the effect of fracturing construction. Currently, there is an urgent need for a method for evaluating and processing the volume of fracturing fractures throughout the life cycle. Embodiments of the present invention comprehensively evaluate the volume of fractures during the entire cycle of the pressure drop during fracturing construction, shut-in pressure drop, flowback pressure drop, and dynamic production process of a fractured well, achieving a rapid evaluation of the fracturing construction effect of the well section to be evaluated throughout the life cycle.

[0039] The following uses detailed examples for detailed description.

[0040] Figure 1 It is a schematic flow chart of the method for evaluating and processing the volume of fracturing fractures throughout the life cycle provided by the embodiments of the present invention. The execution subject of this embodiment can be a computer device. As Figure 1 shown, the method includes:

[0041] Step A: Obtain the fracturing construction pumping parameters and on-site geological parameters of the on-site volume fracturing construction, and input the fracturing construction pumping parameters and on-site geological parameters into reservoir simulation software for numerical simulation. During the numerical simulation process, fit the pressure drop during fracturing construction, simulate the actual formation fracture propagation pattern, and obtain the fracturing transformation volume of the entire horizontal well section.

[0042] Specifically, the fracturing construction pumping parameters include: the viscosity, density, and type of fracturing fluid; the proportion of different types of fracturing fluid; the injection time and injection volume of different types of fracturing fluid; the density, size, and type of proppant; the injection volume of proppant in different stages; after the pumping stops after the pumping is completed, obtain the construction pressure drop data through on-site pressure statistics; the on-site geological parameters include: the Young's modulus and Poisson's ratio of the target formation obtained according to the uniaxial compression test.

[0043] Among them, the on-site pressure construction pumping parameters are obtained through statistics: 1) Record the viscosity (mPa·s), density (g / cm 3 ) and type of fracturing fluid; 2) The proportion of different types of fracturing fluid (such as water-based fracturing fluid, oil-based fracturing fluid, etc.): 3) The injection time and injection volume of different types of fracturing fluid; 4) The density (g / cm 3 ), size (mesh number), and type of proppant; 5) The injection volume of proppant in different stages; after the pumping stops after the pumping is completed, obtain the construction pressure drop data through on-site pressure statistics; the on-site geological parameters include: the Young's modulus (GPa) and Poisson's ratio of the target formation obtained according to the uniaxial compression test.

[0044] Integrate the fracturing construction pumping parameters and on-site geological parameters, and input them into unconventional shale oil reservoir simulation software for numerical simulation. Among them, the unconventional shale oil reservoir simulation software includes but is not limited to: eclipse, cmg, petro, etc.

[0045] Step B: Obtain the bottom-hole flowing pressure data during the shut-in period, draw a flow characteristic curve based on the bottom-hole flowing pressure data, and divide the shut-in pressure drop into multiple flow stages according to the flow characteristic curve; based on the flow stages, establish a pseudo-steady-state flow mathematical model for fracture reservoir control; according to the pseudo-steady-state flow mathematical model for fracture reservoir control, obtain 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; according to 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, obtain the imbibition energy-increasing volume of the entire well.

[0046] Specifically, step B specifically includes:

[0047] SB1: Obtain the bottom-hole flowing pressure data during the shut-in period, and draw a flow characteristic curve based on the bottom-hole flowing pressure data, where the characteristic curve includes a pressure drop curve and a pressure drop derivative curve.

[0048] SB2: Divide the shut-in pressure drop into nine flow stages according to the pressure drop curve and the pressure drop derivative curve, where the nine flow stages include four flow stages under the control of the fractures at the end section, four flow stages under the control of the fractures in the entire well section, and a flow stage under the control of the matrix;

[0049] Reference Figure 2 , Figure 2 is a schematic diagram of the pressure drop curve and the pressure drop derivative curve provided by the embodiment of the present invention. Among them, the fracturing fractures of the shale reservoir in this embodiment belong to Figure 2 the curve of "weak end connectivity + large secondary fracture scale" in

[0050] Among them, the four flow stages under the control of the fractures at the end section include: the first stage ( Figure 2 ① in Figure 2 ), the wellbore afterflow control stage, where the pressure drop curve and the pressure drop derivative curve coincide and the slope is 1; the second stage ( Figure 2 ② in Figure 2 ), the end extension stage, where the slope of the pressure drop derivative curve is 0; the third stage (

[0051] ③ in Figure 2 ), the linear stage inside the fracture before closure, where the slope of the pressure drop derivative curve is 1 / 2; the fourth stage ( Figure 2 ④ in Figure 2 ), the fracture closure control stage, where the slope of the pressure drop derivative curve is greater than 1 / 2; Figure 2In ⑧), during the secondary fracture storage stage, the curve of the pressure drop derivative shows a positive slope;

[0052] Among them, the flow stage under matrix control is: the ninth stage ( Figure 2 In ⑨), during the matrix flow control stage, the curve of the pressure drop derivative shows a negative slope until the pressure drop is zero.

[0053] SB3: Establish a pseudo-steady state flow mathematical model for controlling the storage of main and secondary fractures:

[0054] Main fracture:

[0055] Secondary fracture:

[0056] Among them

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

[0058] SB4: Perform numerical simulation through reservoir simulation software to obtain the fluid leakage rate q m from the fracture to the matrix during the shut-in period and the cumulative fluid leakage volume Q m from the fracture to the matrix during the shut-in period; obtain the compressibility C hf of the main fracture through the fracture conductivity test.and the secondary fracture compressibility coefficient C sf ; Obtain the fracturing fluid volume coefficient B by querying the oilfield data w ;

[0059] SB5: When the bottom-hole flowing pressure data during the shut-in period is in the sixth stage, use the pressure drop data in the sixth stage to plot the characteristic curve of the normalized pressure and the material balance time in a rectangular coordinate system, where the normalized pressure is (p i -p w ) / q m , and the material balance time is Q m / q m ; Obtain the slope value m of the characteristic curve f ;

[0060] SB6: According to the pseudo-steady state flow mathematical model controlled by the main fracture reservoir, obtain Import the known C hf , and obtain the effective volume V ehf of the main fracture in the entire well section as follows:

[0061]

[0062] SB7: When the bottom-hole flowing pressure data during the shut-in period is in the eighth stage, use the pressure drop data in the eighth stage to plot the characteristic curve of the normalized pressure and the material balance time in a rectangular coordinate system, where the normalized pressure is (p i -p w ) / q m , and the material balance time is Q m / q m ; Obtain the slope value m of the characteristic curve F ;

[0063] SB8: According to the pseudo-steady state flow mathematical model controlled by the secondary fracture reservoir, obtain Import the known C sf , and obtain the effective volume V esf of the secondary fracture as follows:

[0064]

[0065] SB9: Add the effective volume V ehf of the main fracture in the entire well section and the obtained effective volume V esf of the secondary fracture to obtain the total effective fracture volume V ef in the entire well section after fracturing, which is the imbibition energy-increasing volume in the entire well.

[0066] Step C: Obtain the bottom-hole pressure data during the flowback period, and use the bottom-hole pressure data to plot the double logarithmic curve of the normalized pressure and the material balance time, that is, the RNP curve; Calculate the cumulative oil production N according to the RNP curveps 、 Cumulative water production volume W ps ; Calculate the average pressure in the fracture control system at different times according to the assumed fracture control water volume N and fracture control oil volume W Calculate the water and oil phase pseudo-pressure differences at each time according to the average pressure in the fracture control system at different times, and plot the curves of the normalized production rate and normalized cumulative production rate of the water and oil phases; Use the curves to iteratively calculate and obtain the water storage volume W in the fracture control effective volume and the crude oil storage volume N in the fracture control effective volume; Calculate the matrix pore volume contributing to oil production according to the water and oil storage volumes in the fracture control effective volume.

[0067] Specifically, step C specifically includes:

[0068] The specific steps of step C include:

[0069] SC1: Obtain the bottom-hole pressure data during the flowback period, and use the bottom-hole pressure data to plot a double logarithmic curve of the normalized pressure and the material balance time, that is, the RNP curve; The calculation formula of the RNP curve is:

[0070]

[0071] t MB =Q x / q x

[0072] In the formula, RNP is the normalized pressure; x - water phase w or oil phase o; P fi - Initial average pressure in the fracture, MPa; P wf - Bottom-hole flowing pressure, MPa; q x - Production rate of water phase or oil phase, m 3 / d; t MB - Material balance time, d (days); Q x - Cumulative production volume of water phase or oil phase, m 3 ; Since it is difficult to obtain the actual pressure in the fracture, it is assumed that the average pressure in the fracture at the initial stage of flowback is approximately equal to the bottom-hole flowing pressure on the first day of flowback, that is, P fi is equal to the bottom-hole flowing pressure P wfi at the time of well opening;

[0073] Reference Figure 3 , Figure 3 is a schematic diagram of the double logarithmic curve of the normalized pressure and the material balance time provided by the embodiment of the present invention.

[0074] When a straight line segment with a slope of 1 appears in the RNP curve ( Figure 3 shown as "stage FR2" in o ), it is the initial moment of the end of the primary fracture stage and the beginning of the pseudo-steady state stage in the fracture control area. Intercept the oil phase flow rate q o and the water phase flow rate qw and bottom-hole flowing pressure p wf ; Determine the bottom-hole flowing pressure at the start of pseudo-steady state as the average pressure p in the fracture-controlled area i .

[0075] SC2: Obtain the total sand volume V added to the well through the pressure construction report p ; Obtain the water-phase compressibility coefficient C through the high-pressure physical properties parameters of formation fluids w , oil-phase compressibility coefficient C o , water-phase initial volume coefficient B wi , oil-phase initial volume coefficient B oi , initial crude oil viscosity μ oi , water-phase initial viscosity μ wi and relative permeability curve; Assume the water storage W in the fracture-controlled effective volume and the crude oil storage N in the fracture-controlled effective volume; Obtain the effective volume V of the main fracture and the effective volume V of the secondary fracture according to step B ehf and the effective volume V of the secondary fracture esf .

[0076] SC3: Assign reasonable water storage W in the fracture-controlled effective volume and crude oil storage N in the fracture-controlled effective volume according to the oilfield data; And calculate the average pressure in the fracture-controlled system at different times through the following formula

[0077]

[0078] V mp = B wi W + B oi N - V ehf - V esf

[0079]

[0080] In the formula Average pressure in the fracture-controlled system; W ps Is the volume of returned drainage water; N ps Is the volume of produced crude oil; V mp Is the fracture-controlled matrix pore volume; C hf Is the compressibility coefficient of the main fracture; C sf Is the compressibility coefficient of the secondary fracture; C m Is the compressibility coefficient of the matrix pores; B w Is the volume coefficient of the fracturing fluid, m 3 / m 3 ; B o Is the volume coefficient of crude oil, m 3 / m 3 ; p n Is the propping pressure in the fracturec is the net closure pressure in the fracture; t is the number of days of well opening and backflow.

[0081] SC4: According to the average pressure of the fracture control system at each moment Use the formula to calculate the pseudo-pressure difference of the aqueous phase at each moment (p pi,w -p pwf,w ), the pseudo-pressure difference of the oil phase (p pi,o -p pwf,o ),

[0082]

[0083]

[0084] In the formula, p pi,w is the initial pseudo-pressure of the aqueous phase, MPa; p pwf,w is the pseudo-bottom hole flowing pressure of the aqueous phase; is the pseudo-average pressure of the aqueous phase in the fracture control area; μ wi is the initial viscosity of the aqueous phase; B wi is the initial volume coefficient of the aqueous phase; μ w (p) is the viscosity of the aqueous phase at pressure p; B w (p) is the volume coefficient of the aqueous phase at pressure p; k rw (p) is the relative permeability of the aqueous phase at pressure p in the fracture control area;

[0085]

[0086] In the formula: p pi,o is the initial pseudo-pressure of the oil phase, MPa; p pwf,o is the pseudo-bottom hole flowing pressure of the oil phase; is the pseudo-average pressure of the oil phase in the 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 at pressure p in the fracture control area;

[0087] SC5: Take the curves of the normalized production rates of the aqueous phase and the oil phase as the vertical axis respectively, and the normalized cumulative production rates of the aqueous phase and the oil phase as the horizontal axis to draw the target curve; where the curve of the normalized production rate of the aqueous phase is the curve of the normalized production rate of the oil phase is the curve of the normalized cumulative production rate of the aqueous phase is the curve of the normalized cumulative production rate 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 controlled by the fracture and the oil reserve N in the effective volume controlled by the fracture obtained;

[0088] SC6: Compare the water reserve W in the effective volume controlled by the fracture and the oil reserve N in the effective volume controlled by the fracture obtained in step SC5 with the water reserve W in the effective volume controlled by the fracture and the oil reserve N in the effective volume controlled by the fracture assumed in step 3. If the error condition is not met, use the calculation result of step SC5 as the assumption condition for step SC3, and repeat the calculation of steps SC3 - SC5 until the water reserve W in the effective volume controlled by the fracture and the oil reserve N in the effective volume controlled by the fracture that meet the error condition are obtained.

[0089] SC7: Add the obtained water reserve W in the effective volume controlled by the fracture and the oil reserve N in the effective volume controlled by the fracture to get the matrix pore volume V contributing to oil production mp 。

[0090] Step D: Obtain the open-well production rate q and the cumulative oil production N p ; Based on the open-well production rate q and the cumulative oil production N p , establish the relationship between the open-well production rate q and the cumulative oil production N p , and obtain the coefficients a and m of the relationship; Use the coefficients of the relationship between the open-well production rate q and the cumulative oil production N p , and obtain the relationship between the open-well production rate q and the production time t, and obtain q 1 and q ∞ ; Calculate the recoverable reserve per well of the oil well under the specified years.

[0091] Among them, step D specifically includes:

[0092] SD1: Obtain the open-well production rate q and the cumulative oil production N p , and establish the relationship between the open-well production rate q and the cumulative oil production N p , which is:

[0093]

[0094] In the formula, t is the open-well flowback days, and the values of a and m are coefficients;

[0095] Make a double logarithmic curve of (q / N p ) - t to calculate the values of a and m.

[0096] SD2: Take the production rate on the first day of the decline start stage as q 1 , and based on the following formula, fit the relationship between the production rate q and the time t to obtain q ∞ :

[0097]

[0098] q = q 1 t(a, m) + q ∞

[0099] In the formula, q ∞ is the intercept of the straight line made by q and t(a, m).

[0100] SD3: Using the formula in step SD2, predict the recoverable reserves per well of the oil well under the specified number of years. The formula is as follows:

[0101] EUR = ∑q

[0102] In the formula, EUR is the recoverable reserves per well.

[0103] In summary, the embodiment of the present invention comprehensively evaluates the fracture volume during the entire life cycle of the fracturing well in the fracturing construction pressure drop, shut-in pressure drop, flowback pressure drop, and dynamic production process, and realizes the rapid evaluation of the fracturing construction effect of the well section to be evaluated during the entire life cycle.

[0104] The following uses specific application examples to illustrate the full-life-cycle fracturing fracture volume evaluation processing method provided by the embodiment of the present invention.

[0105] 1) For a certain target well (shale oil well), according to the geological parameters of the target formation and the actual on-site construction pumping program, simulate the process of fracture propagation. Immediately shut in the well after the pumping is completed to obtain the construction pressure drop data of the simulated fracture. Obtain the fracturing construction pumping parameters and on-site geological parameters of the on-site volume fracturing construction, and input the fracturing construction pumping parameters and on-site geological parameters into the reservoir simulation software for numerical simulation. During the numerical simulation process, fit the fracturing construction pressure drop and simulate the actual formation fracture propagation morphology (such as Figure 4 shown), and obtain the fracturing reconstruction volume of the entire horizontal well section.

[0106] In the double logarithmic coordinate system, plot the pressure drop curve and the pressure drop derivative curve respectively for the simulated construction pressure drop data and the construction pressure drop data recorded during the actual construction, and perform curve fitting, as Figure 5 shown. Figure 5 As shown in, the fitting effect is good, indicating that the relevant parameters of the simulated fracture can explain the actual construction effect. The SRV of the reservoir reconstruction volume interpreted for this well is 54420 m 3 . Perform flow regime diagnosis on the characteristic slope section of the pressure drop derivative curve to identify different stages of fracture closure.

[0107] 2) Statistically analyze the bottom-hole flowing pressure data during the shut-in period, analyze the bottom-hole pressure drop characteristics of the pressure drop and the double logarithmic analysis of the pressure drop derivative, and plot the double logarithmic curve of the pressure drop and its natural logarithm derivative during the shut-in period of the target well (i.e., the characteristic curve includes the pressure drop curve and the pressure drop derivative curve).

[0108] Based on the flow regime identification results in the figure, the characteristic curves of flow stages ⑥ and ⑧ are respectively plotted in the rectangular coordinate system, and then the relevant parameters are inversely calculated using the established closed - well pressure drop calculation model. Refer to Figure 6 and Figure 7 , Figure 6 is the double - logarithmic curve of the normalized pressure and the material balance time for flow stage ⑥ provided by the embodiment of the present invention; Figure 7 is the double - logarithmic curve of the normalized pressure and the material balance time for flow stage ⑧ provided by the embodiment of the present invention.

[0109] The effective volume V ehf of the main fracture in the whole well section is calculated to be 13663 m 3 , the effective volume V esf of the secondary fracture is 37231 m 3 , and the imbibition - enhanced energy volume of the whole well is 50894 m 3 . 3)

[0111] 1. Collect and sort out the oil well production data q o 、q w and the wellhead pressure, and calculate the corresponding N p 、W p 、p i_start = 66.29 MPa, p wf values.

[0112] 2. According to the derivative RNP curve of the normalized pressure, determine the pseudo - steady flow stage in the fracture - controlled area. After 124 days, the slope of the RNP curve is 1, and the oil well enters the pseudo - steady stage in the fracture - controlled area. At the same time, determine the end time of the fracture storage stage, and the average pressure p i in the fracture - controlled area = 60.48 MPa;

[0113] 3. Collect the fracturing sand - adding data V p = 7200 m 3 , and the high - pressure physical property parameters C w = 4×10 -4 MPa -1 、C o＝ 24.7×10 -4 MPa -1 、B wi = 1.01、B oi = 1.06, μ oi = 8 mPa·s, μ wi = 2 mPa·s, the relative permeability curve, and collect the main and secondary fracture data calculated by the closed - well model in the second stage, V ehf is 13663 m 3 , V esfIt is 37231 m 3 ;

[0114] 4. Assume that the water reserve W in the effectively controlled fracture volume is 5×10 5 m 3 and the oil reserve N is 5×10 5 m 3 . Taking the curves of the normalized production rates of the water phase and the oil phase as the vertical axis and the normalized cumulative production rates of the water phase and the oil phase as the horizontal axis, plot the target curve (flow material balance curve); extend the straight-line part of the target curve until it intersects the x-axis, and the intersection point is the water reserve W in the effectively controlled fracture volume and the crude oil reserve N in the effectively controlled fracture volume obtained.

[0115] Refer to Figure 8 , Figure 8 which is the flow material balance curve of the oil phase (i.e., the target curve of the oil phase); refer to Figure 9 , Figure 9 which is the flow material balance curve of the water phase (i.e., the target curve of the water phase).

[0116] 5. Compare the calculated results obtained above with the assumed values. If the error does not meet the accuracy requirements, then take the calculated results as the assumed conditions and repeat the calculation in step 4 until the errors of the calculated water and oil reserves meet the requirements. As shown in Figure 8 , 9 , N = 10.546×10 4 m 3 , W = 5.063×10 4 m 3 .

[0117] Calculate the matrix pore volume V mp contributing to oil production, which is 64.763×10 4 m 3 , that is, the fracture volume contributing to oil production (DRV) is 64.763×10 4 m 3 . 4)

[0119] 1. Plot the double-logarithmic curve of (q / Np)—t for Well X, fit the power function, and obtain a = 1.1109 and m = 1.077. When selecting the straight-line segment, if the regression coefficient R 2 is greater than 0.95, it is considered a suitable straight-line segment, as shown in Figure 10 . Refer to Figure 10 , Figure 10 which is the relationship curve between the production rate q and the cumulative oil production N p during the open-well production.

[0120] 2. Find the production rate q 1 and q ∞:Taking the actual production q as the vertical coordinate and t(a,m) as the horizontal coordinate, draw a linear coordinate line, as Figure 11 shown, fit a straight line to obtain q 1 = 48.58t / d and q ∞ = -0.221t / d for two parameters.

[0121] 3. Production prediction: After obtaining a, m, and q 1 , use the formula for production prediction, and predict the cumulative production in 10 years as the EUR (estimated ultimate recovery) of a single well of this shale oil well to be 43,670 tons.

[0122] Corresponding to the full-life-cycle fracture volume evaluation and treatment method of the above-mentioned embodiment, Figure 12 is the structural block diagram of the full-life-cycle fracture volume evaluation and treatment device provided by the embodiment of the present invention. For the sake of convenience of description, only the parts related to the embodiment of the present invention are shown.

[0123] Referring to Figure 12 , the full-life-cycle fracture volume evaluation and treatment device includes: a fracture stimulation fracture volume processing module 11, a whole-well imbibition energy-increasing volume processing module 12, an oil-producing contributing matrix pore volume processing module 13, and a single-well recoverable reserve processing module 14.

[0124] The fracture stimulation fracture volume processing module 11 is used to obtain the fracture stimulation pumping parameters and on-site geological parameters of the on-site volume fracture stimulation construction, input the fracture stimulation pumping parameters and on-site geological parameters into reservoir simulation software for numerical simulation, fit the fracture stimulation pressure drop during the numerical simulation, simulate the actual formation fracture propagation morphology, and obtain the fracture stimulation volume of the entire horizontal well section;

[0125] The whole-well imbibition energy-increasing volume processing module 12 is used to obtain the bottom-hole flowing pressure data during the shut-in period, draw a flow characteristic curve according to the bottom-hole flowing pressure data, divide the shut-in pressure drop into multiple flow stages based on the flow characteristic curve; based on the flow stage, establish a pseudo-steady-state flow mathematical model for fracture reservoir control; according to the pseudo-steady-state flow mathematical model for fracture reservoir control, obtain 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; according to 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, obtain the whole-well imbibition energy-increasing volume;

[0126] The oil-producing contributing matrix pore volume processing module 13 is used to obtain the bottom-hole pressure data during the flowback period, draw a double-logarithmic curve of the normalized pressure and the material balance time, i.e., the RNP curve, according to the bottom-hole pressure data; calculate the cumulative oil production Nps and the cumulative water production Wps according to the RNP curve; calculate the average pressure in the fracture control system at different times according to the assumed fracture-controlled water volume N and fracture-controlled oil volume W Calculate the water and pseudo-pressure differences at each moment based on the average pressure in the seam control system at different moments, and plot the curves of the normalized production and normalized cumulative production of water and oil phases; use the curves to iteratively calculate and obtain the water storage W in the effective volume controlled by the seam and the original oil storage N in the effective volume controlled by the seam; calculate the matrix pore volume contributing to oil production based on the water and oil storages in the effective volume controlled by the seam.

[0127] The single-well recoverable reserve processing module 14 is used to obtain the production rate q and the cumulative oil production Np during open-well production; establish a relationship between the production rate q and the cumulative oil production Np based on the production rate q and the cumulative oil production Np during open-well production, and obtain the coefficients a and m of the relationship; use the coefficients of the relationship between the production rate q and the cumulative oil production Np, and obtain the relationship between the production rate q and the production time t, and obtain q1 and q ∞ ; Calculate the single-well recoverable reserve of the oil well under the specified number of years.

[0128] In a possible design, the full-well imbibition energy-increasing volume processing module is specifically used for:

[0129] Obtain the bottom-hole flowing pressure data during the shut-in period, and plot the flow characteristic curves based on the bottom-hole flowing pressure data, where the characteristic curves include the pressure-drop curve and the pressure-drop derivative curve;

[0130] Divide the shut-in pressure drop into nine flow stages according to the pressure-drop curve and the pressure-drop derivative curve, where the nine flow stages include four flow stages under the control of the end-section fracture, four flow stages under the control of the full-well fracture, and the flow stage under the control of the matrix;

[0131] Among them, the four flow stages under the control of the end-section fracture include: the first stage, the wellbore afterflow control stage, where the pressure-drop curve and the pressure-drop derivative curve coincide and the slope is 1; the second stage, the end extension stage, where the slope of the pressure-drop derivative curve is 0; the third stage, the linear stage in the fracture before closure, where the slope of the pressure-drop derivative curve is 1 / 2; the fourth stage, the fracture closure control stage, where the slope of the pressure-drop derivative curve is greater than 1 / 2;

[0132] Among them, the four flow stages under the control of the full-well fracture include: the fifth stage, the end-section - front-section connection control stage, where the curve of the pressure-drop derivative shows a negative slope; the sixth stage, the main-fracture storage stage, where the curve of the pressure-drop derivative shows a positive slope; the seventh stage, the crossflow control stage between the main and secondary fractures, where the curve of the pressure-drop derivative shows a negative slope; the eighth stage, the secondary-fracture storage stage, where the curve of the pressure-drop derivative shows a positive slope;

[0133] Among them, the flow stage under the control of the matrix is: the ninth stage, the matrix flow control stage, where the curve of the pressure-drop derivative shows a negative slope until the pressure drop is zero;

[0134] Establish a pseudo-steady state flow mathematical model for controlling the storage of main and secondary fractures:

[0135] Main fracture:

[0136] Secondary fracture:

[0137] Where

[0138] In the formula, p i is the initial formation pressure, MPa; p w is the bottom-hole pressure, MPa; q m is the cross-flow rate of the fracture into the matrix during the shut-in period, obtained by simulating the shut-in time based on the imbibition experiment law, m 3 / d; Q m is the cumulative cross-flow rate of the fracture into the matrix during the shut-in period, m 3 ; B w is the volume coefficient of the fracturing fluid, m 3 / m 3 ; V ehf is the effective fracture volume of the main fracture, m 3 ; C hf is the compressibility of the main fracture, MPa -1 ; is the fracture porosity, decimal; k f is the fracture permeability, mD; μ f is the viscosity of the fracturing fluid, mPa·s; L f is the half-length of the main fracture; C t is the compressibility of the rock, MPa -1 ; V esf is the effective fracture volume of the secondary fracture, m 3 ; C sf is the compressibility of the secondary fracture, MPa -1 ; C f is the comprehensive compressibility of the fracture;

[0139] Through numerical simulation with reservoir simulation software, obtain the cross-flow rate q m of the fracture into the matrix during the shut-in period and the cumulative cross-flow rate Q m of the fracture into the matrix during the shut-in period; through the fracture conductivity test, obtain the compressibility C hf of the main fracture and the compressibility C sf of the secondary fracture; obtain the volume coefficient B w of the fracturing fluid by querying the oilfield data;

[0140] When the bottom-hole flowing pressure data during the shut-in period is in the sixth stage, use the pressure drop data in the sixth stage to plot the characteristic curve of the normalized pressure vs. the material balance time in the rectangular coordinate system, where the normalized pressure is (pi -p w ) / q m , the material balance time is Q m / q m ; Obtain the slope value m of the characteristic curve f ;

[0141] According to the pseudo-steady state flow mathematical model controlled by the main fracture reservoir, obtain Import the known C hf , and obtain the effective volume V of the main fractures in the whole well section ehf as follows:

[0142]

[0143] When the bottom-hole flowing pressure data during the shut-in period is in the eighth stage, use the pressure drop data in the eighth stage to plot the characteristic curve of the normalized pressure and the material balance time in a rectangular coordinate system, where the normalized pressure is (p i -p w ) / q m , the material balance time is Q m / q m ; Obtain the slope value m of the characteristic curve F ;

[0144] According to the pseudo-steady state flow mathematical model controlled by the secondary fracture reservoir, obtain Import the known C sf , and obtain the effective volume V of the secondary fractures esf as follows:

[0145]

[0146] Add the effective volume V of the main fractures in the whole well section ehf and the obtained effective volume V of the secondary fractures esf to obtain the total effective fracture volume V after fracturing in the whole well section ef , which is the imbibition energy-increasing volume in the whole well section.

[0147] Figure 13 This is the schematic diagram of the hardware structure of the computer device provided by the embodiment of the present invention. As Figure 13 shown, the computer device of this embodiment includes: a processor 21 and a memory 22; where

[0148] The memory 22 is used to store computer execution instructions;

[0149] The processor 21 is used to execute the computer execution instructions stored in the memory to implement the respective steps executed by the computer device in the above embodiments. Specifically, reference can be made to the relevant descriptions in the foregoing method embodiments.

[0150] Optionally, the memory 22 can be either independent or integrated with the processor 21.

[0151] When the memory 22 is independently provided, the computer further includes a bus 23 for connecting the memory 22 and the processor 21.

[0152] An embodiment of the present invention further provides a computer-readable storage medium, in which computer-executable instructions are stored. When the processor executes the computer-executable instructions, the full-life-cycle fracturing crack volume evaluation processing method as described above is implemented.

[0153] An embodiment of the present invention further provides a computer program product, including a computer program. When the computer program is executed by the processor, the full-life-cycle fracturing crack volume evaluation processing method as described above is implemented.

[0154] In several embodiments provided by the present invention, it should be understood that the disclosed devices and methods can be implemented in other ways. For example, the device embodiments described above are merely illustrative. For example, the division of the modules is only a logical function division. In actual implementation, there may be other division methods. For example, multiple modules can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the displayed or discussed couplings or direct couplings or communication connections to each other can be through some interfaces. The indirect couplings or communication connections of the devices or modules can be in electrical, mechanical or other forms.

[0155] The modules described as separate components may or may not be physically separated. The components displayed as modules may or may not be physical units, that is, they can be located in one place or distributed to multiple network units. Some or all of the modules can be selected according to actual needs to implement the solution of this embodiment.

[0156] In addition, in each embodiment of the present invention, the functional modules can be integrated in a processing unit, or each module can exist physically alone, or two or more modules can be integrated in one unit. The units formed by the above modules can be implemented in the form of hardware or in the form of a hardware plus software functional unit.

[0157] The integrated modules implemented in the form of software functional modules can be stored in a computer-readable storage medium. The above software functional modules are stored in a storage medium, including several instructions for causing a computer device (which can be a personal computer, a server, or a network device, etc.) or a processor to execute some steps of the methods described in various embodiments of the present application.

[0158] It should be understood that the above-mentioned processor may be a Central Processing Unit (CPU), or may also be other general-purpose processors, Digital Signal Processors (DSPs), Application Specific Integrated Circuits (ASICs), etc. The general-purpose processor may be a microprocessor or any conventional processor, etc. The steps of the method disclosed in combination with the invention can be directly embodied as being executed and completed by a hardware processor, or can be executed and completed by a combination of hardware and software modules in the processor.

[0159] The memory may include high-speed RAM memory, and may also include 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 disc, etc.

[0160] The bus may be an Industry Standard Architecture (ISA) bus, a Peripheral Component Interconnect (PCI) bus, an Extended Industry Standard Architecture (EISA) bus, etc. The bus can be divided into an address bus, a data bus, a control bus, etc. For the sake of convenience in representation, the buses in the drawings of this application are not limited to only one bus or one type of bus.

[0161] The above-mentioned 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, a magnetic disk, or an optical disc. The storage medium can be any available medium that can be accessed by a general-purpose or special-purpose computer.

[0162] An exemplary storage medium is coupled to the processor, enabling the processor to 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 master control device.

[0163] Those of ordinary skill in the art will understand that all or part of the steps of implementing the above 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, it performs the steps of the above method embodiments; and the aforementioned storage medium includes: various media such as ROM, RAM, magnetic disks, or optical discs that can store program codes.

[0164] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention and are not intended to limit them; although the present invention has been described in detail with reference to the foregoing embodiments, those of ordinary skill in the art should understand that they can still modify the technical solutions described in the foregoing embodiments, or perform equivalent replacements for some or all of the technical features; and 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 invention.

Claims

1. A method for evaluating and processing the volume of fracturing fractures in the whole life cycle, characterized in that, it includes: Step A: Obtain the fracturing construction pumping parameters and on-site geological parameters of the on-site volume fracturing construction, and input the fracturing construction pumping parameters and on-site geological parameters into reservoir simulation software for numerical simulation. During the numerical simulation process, fit the pressure drop during fracturing construction, simulate the actual formation fracture propagation pattern, and obtain the fracturing reconstruction volume of the entire horizontal well section; Step B: Obtain the bottom-hole flowing pressure data during the shut-in period, draw a flow characteristic curve based on the bottom-hole flowing pressure data, and divide the shut-in pressure drop into multiple flow stages according to the flow characteristic curve; based on the flow stage, establish a pseudo-steady-state flow mathematical model for fracture storage control; according to the pseudo-steady-state flow mathematical model for fracture storage control, obtain 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; according to 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, obtain the imbibition energy-increasing volume of the entire well; Step C: Obtain the bottom-hole pressure data during the flowback period, and use the bottom-hole pressure data to plot a double logarithmic curve of the normalized pressure versus the material balance time, i.e., the RNP curve; calculate the cumulative oil production N according to the RNP curve. ps and the cumulative water production W ps ; calculate the average pressure in the fracture-controlled system at different times according to the assumed fracture-controlled water volume N and fracture-controlled oil volume W. Calculate the water-phase and oil-phase pseudo-pressure differences at each time according to the average pressure in the fracture-controlled system at different times, and plot the curves of the normalized production and the normalized cumulative production of water and oil phases; use the curves to iteratively calculate and obtain the water storage W in the fracture-controlled effective volume and the crude oil storage N in the fracture-controlled effective volume; calculate the matrix pore volume contributing to oil production according to the water and oil storages in the fracture-controlled effective volume. Step D: Obtain the open - well production rate q and the cumulative oil production N p ; According to the open - well production rate \(q\) and the cumulative oil production \(N\) p , establish the relationship between the open - well production rate \(q\) and the cumulative oil production \(N\) p , and obtain the coefficients \(a\) and \(m\) of the relationship Using the coefficient of the relationship between the open - well production rate q and the cumulative oil production N p to obtain the relationship between the open - well production rate q and the production time t, and obtain q 1 and q ∞ ; Calculate the recoverable reserves per well of the oil well under the specified number of years; The specific content of step D includes: SD1: Obtain the open - well production rate q and the cumulative oil production N p , and establish the relationship between the open - well production rate q and the cumulative oil production N p , which is: In the formula, t is the number of days of open-hole backflow, and a and m are coefficients; Production (q / N p )—t double logarithmic curve, calculate the values of a and m; SD2: The production on the first day of the decreasing start-up phase is q 1 , according to the following formula, fit the relationship between the production output q and the time t, and obtain q ∞ : q = q 1 t(a, m)+q ∞ where q ∞ is the intercept of the straight line formed by q and t(a, m); SD3: Use the formula in step SD2 to predict the recoverable reserves per well of the oil well under the specified number of years. The formula is as follows: EUR = ∑q In the formula, EUR is the recoverable reserves per well.

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

3. The method according to claim 1, characterized in that, the specific content of step B includes: Obtain the bottom-hole flowing pressure data during the shut-in period, and draw a flow characteristic curve based on the bottom-hole flowing pressure data, where the characteristic curve includes a pressure drop curve and a pressure drop derivative curve; Divide the shut-in pressure drop into nine flow stages according to the pressure drop curve and the pressure drop derivative curve. Among them, the nine flow stages include four flow stages under the control of the end-section fractures, four flow stages under the control of the fractures in the entire well section, and a flow stage under the control of the matrix; Among them, the four flow stages under the control of the end-section fractures include: the first stage, the wellbore afterflow control stage, where the pressure drop curve and the pressure drop derivative curve coincide and the slope is 1; the second stage, the end extension stage, where the slope of the pressure drop derivative curve is 0; the third stage, the linear stage inside the fracture before closure, where the slope of the pressure drop derivative curve is 1 / 2; the fourth stage, the fracture closure control stage, where the slope of the pressure drop derivative curve is greater than 1 / 2; Among them, the four flow stages under the control of fractures in the whole well section include: the fifth stage, the connection control stage of the end section - the front section, where the curve of the pressure drop derivative shows a negative slope; the sixth stage, the main fracture storage stage, where the curve of the pressure drop derivative shows a positive slope; the seventh stage, the cross - flow control stage between the main and secondary fractures, where the curve of the pressure drop derivative shows a negative slope; the eighth stage, the secondary fracture storage stage, where the curve of the pressure drop derivative shows a positive slope; Among them, the flow stage under the control of the matrix is: the ninth stage, the matrix flow control stage, where the curve of the pressure drop derivative shows a negative slope until the pressure drop is zero; Establish a pseudo - steady - state flow mathematical model for the control of the main and secondary fracture storages: Main crack: Secondary crack: Among them where p i is the initial formation pressure, MPa; p w is the bottom-hole pressure, MPa; q m is the fluid loss from the fracture to the matrix during the shut-in period, obtained by simulating the shut-in time based on the imbibition experiment law, m 3 / d; Q m is the cumulative fluid loss from the fracture to the matrix during the shut-in period, m 3 ; B w is the fracturing fluid volume coefficient, m 3 / m 3 ; V ehf is the effective fracture volume of the main fracture, m 3 ; C hf is the compressibility of the main fracture, MPa -1 ; is the fracture porosity, fraction; k f is the fracture permeability, mD; μ f is the viscosity of the fracturing fluid, mPa·s; L f is the half-length of the main fracture; C t is the compressibility of the rock, MPa -1 ; V esf is the effective fracture volume of the secondary fracture, m 3 ; C sf is the compressibility of the secondary fracture, MPa -1 ; C f is the comprehensive compressibility of the fracture; Through numerical simulation with reservoir simulation software, obtain the cross-flow rate q from the fracture to the matrix during the shut-in period m and the cumulative cross-flow volume Q from the fracture to the matrix during the shut-in period m ; Through the fracture conductivity test, obtain the primary fracture compressibility C hf and the secondary fracture compressibility C sf ; Obtain the fracturing fluid volume coefficient B by querying the oilfield data w ; When the bottom-hole flowing pressure data during the shut-in period is in the sixth stage, use the pressure drop data in the sixth stage to plot the characteristic curve of the normalized pressure and the material balance time in the rectangular coordinate system, where the normalized pressure is (p i - p w ) / q m , and the material balance time is Q m / q m ; obtain the slope value m f ; Based on the pseudo-steady state flow mathematical model controlled by the main fracture reservoir, it is obtained that Import the known C hf , and the effective volume V of the main fractures in the entire well section is obtained ehf as follows: When the bottom-hole flowing pressure data during the shut-in period is in the eighth stage, use the pressure drop data in the eighth stage to plot the characteristic curve of the normalized pressure and the material balance time in the rectangular coordinate system, where the normalized pressure is (p i -p w ) / q m , and the material balance time is Q m / q m ; obtain the slope value m F ; Based on the quasi-steady state flow mathematical model controlled by secondary fracture storage, it is obtained that Import the known C sf , and the effective volume V of the secondary fracture is obtained esf as follows: Add the effective volume V of the main fractures in the entire well section ehf and the obtained effective volume V of the secondary fractures esf to obtain the total effective fracture volume V ef after fracturing in the entire well section, which is the imbibition energy-increasing volume of the entire well.

4. According to the method described in claim 1, characterized in that, the specific steps of step C include: SC1: Obtain the bottom - hole pressure data during the flow - back period, and use the bottom - hole pressure data to draw a double - logarithmic curve of the normalized pressure and the material balance time, that is, the RNP curve; where the calculation formula of the RNP curve is: t MB = Q x / q x Wherein, RNP is the normalized pressure; x is the aqueous phase w or the oil phase o; P fi - The average pressure in the initial fracture, MPa; P wf - The bottom-hole flowing pressure, MPa; q x - The production rate of the aqueous phase or the oil phase, m 3 / d; t MB - The material balance time, d (days); Q x - The cumulative production of the aqueous phase or the oil phase, m 3 ; Since it is difficult to obtain the actual pressure in the fracture, it is assumed that the average pressure in the fracture at the initial stage of flowback is approximately equal to the bottom-hole flowing pressure on the first day of flowback, and P fi is equal to the bottom-hole flowing pressure P wfi ; When a straight line segment with a slope of 1 appears in the RNP curve, it is the end of the primary stage of the fracture and the initial moment of the quasi-steady state stage in the fracture control area. The oil phase flow rate q o and the water phase flow rate q w , as well as the bottom hole flowing pressure p wf are intercepted; the bottom hole flowing pressure at the start of the quasi-steady state is determined as the average pressure p i within the fracture control area; SC2: Obtain the total well sand addition volume V through the pressure construction report p ; Obtain the aqueous phase compressibility C through the formation fluid high-pressure physical property parameters w , the oil phase compressibility C o , the initial aqueous phase volume factor B wi , the initial oil phase volume factor B oi , the initial crude oil viscosity μ oi , the initial aqueous phase viscosity μ wi and the relative permeability curve; Assume the water storage W in the fracture-controlled effective volume and the crude oil reserve N in the fracture-controlled effective volume; Obtain the effective volume V ehf of the main fracture and the effective volume V esf ; SC3: Assign reasonable water reserves W and crude oil reserves N in the effective volume controlled by fractures according to the oilfield data for the assumed water reserves W and crude oil reserves N in the effective volume controlled by fractures; and calculate the average pressure in the fracture control system at different times through the following formula V mp = B wi W + B oi N - V ehf -V esf In the formula, Average pressure in the seam control system; W ps Is the volume of the returned drainage water; N ps Is the volume of the produced crude oil; V mp Is the pore volume of the seam control matrix; C hf Is the main fracture compressibility; C sf Is the secondary fracture compressibility; C m Is the matrix pore compressibility; B w Is the fracturing fluid volume coefficient, m 3 / m 3 ; B o Is the crude oil volume coefficient, m 3 / m 3 ; p n Is the support pressure in the fracture; p c Is the net closure pressure in the fracture; t is the number of days of well-opening and backflow; SC4: According to the average pressure of the slot control system at each moment Use the formula to calculate the pseudo-pressure difference of the aqueous phase (p pi,w -p pwf,w ), the pseudo-pressure difference of the oil phase (p pi,o -p pwf,o ), where p pi,w is the initial pseudo - pressure of the aqueous phase, MPa; p pwf,w is the pseudo - bottom - hole flowing pressure of the aqueous phase; is the pseudo - average pressure in the fracture - controlled region of the aqueous phase; μ wi is the initial viscosity of the aqueous phase; B wi is the initial volume factor of the aqueous phase; μ w (p) is the viscosity of the aqueous phase at pressure p; B w (p) is the volume factor of the aqueous phase at pressure p; k rw (p) is the relative permeability of the aqueous phase in the fracture - controlled region at pressure p; Where: p pi,o is the initial pseudo-pressure of the oil phase, MPa; p pwf,o is the pseudo-bottom-hole flowing pressure of the oil phase; is the pseudo-average pressure in the fracture-controlled area of the oil phase; μ oi is the initial viscosity of the oil phase; B oi is the initial volume factor of the oil phase; μ o (p) is the viscosity of the oil phase at pressure p; B o (p) is the volume factor of the oil phase at pressure p; k ro (p) is the relative permeability of the oil phase in the fracture-controlled area at pressure p; SC5: Taking the curves of the normalized production of the aqueous phase and the oil phase as the vertical axis and the normalized cumulative production of the aqueous phase and the oil phase as the horizontal axis, plot the target curve; wherein the curve of the normalized production of the aqueous phase is The curve of the normalized production of the oil phase is The curve of the normalized cumulative production of the aqueous phase is The curve of the normalized cumulative production of the oil phase is Extend the straight-line part of the target curve to intersect with the x-axis, and the intersection point is the water storage W in the fracture-controlled effective volume and the crude oil storage N in the fracture-controlled effective volume obtained SC6: Compare the water storage W and the crude oil storage N in the fracture - controlled effective volume obtained in step SC5 with the water storage W and the crude oil storage N in the fracture - controlled effective volume assumed in step SC3. If the error condition is not met, use the calculation result of step SC5 as the assumed condition of step SC3, and repeat steps SC3 - SC5 until the water storage W and the crude oil storage N in the fracture - controlled effective volume that meet the error condition are obtained; SC7: Add the water storage W in the obtained effective volume controlled by fractures and the oil reserves N in the effective volume controlled by fractures to obtain the matrix pore volume V contributing to oil production. mp .

5. A device for evaluating and processing the volume of a fracturing fracture in the whole life cycle, characterized in that, it includes: A fracturing and stimulation fracture volume processing module, which is used to obtain the fracturing construction pumping parameters and on - site geological parameters of the on - site volume fracturing construction, and input the fracturing construction pumping parameters and on - site geological parameters into reservoir simulation software for numerical simulation. During the numerical simulation, fit the fracturing construction pressure drop, simulate the actual formation fracture propagation morphology, and obtain the fracturing and stimulation volume of the whole horizontal well section; A whole - well imbibition energy - increasing volume processing module, which is used to obtain the bottom - hole flowing pressure data during the shut - in period, draw a flow characteristic curve according to the bottom - hole flowing pressure data, and divide the shut - in pressure drop into multiple flow stages based on the flow characteristic curve; based on the flow stage, establish a pseudo - steady - state flow mathematical model for the control of fracture storage; according to the pseudo - steady - state flow mathematical model for the control of fracture storage, obtain the effective volume of the main fractures in the whole well section and the effective volume of the secondary fractures in the whole well section; according to the effective volume of the main fractures in the whole well section and the effective volume of the secondary fractures in the whole well section, obtain the whole - well imbibition energy - increasing volume; Oil production contribution matrix pore volume processing module, which is used to obtain bottom-hole pressure data during the flowback period, and draw a double logarithmic curve of normalized pressure and material balance time, i.e., the RNP curve; calculate the cumulative oil production N according to the RNP curve ps , the cumulative water production W ps ; calculate the average pressure in the fracture control system at different times according to the assumed fracture-controlled water volume N and fracture-controlled oil volume W Calculate the water-phase and oil-phase pseudo-pressure differences at each moment according to the average pressure in the fracture control system at different times, and draw curves of the normalized production and normalized cumulative production of water and oil phases; use the curves to iteratively calculate and obtain the water storage W in the fracture control effective volume and the crude oil storage N in the fracture control effective volume; calculate the oil production contribution matrix pore volume according to the water and oil storage in the fracture control effective volume; Single-well recoverable reserve processing module, used to obtain the open-well production output q and the cumulative oil production N p ; According to the open - well production rate \(q\) and the cumulative oil production \(N\) p , establish the relationship between the open - well production rate \(q\) and the cumulative oil production \(N\) p , and obtain the coefficients \(a\) and \(m\) of the relationship Using the coefficient of the relationship between the open - well production rate q and the cumulative oil production N p to obtain the relationship between the open - well production rate q and the production time t, and obtain q 1 and q ∞ ; calculate the recoverable reserves per well of the oil well under the specified number of years; The single-well recoverable reserve processing module is used to obtain the open-well production output q and the cumulative oil production N p , and establish the relationship between the open-well production output q and the cumulative oil production N p , which is: In the formula, t is the number of days of well opening and flow - back, and a and m are coefficients; Production (q / N p )—t double logarithmic curve, calculate a and m values; Starting from the production output q on the first day of the decreasing start-up phase 1 , according to the following formula, the relationship between the production output q and the time t is fitted to obtain q ∞ : q = q 1 t(a, m) + q ∞ where q ∞ is the intercept of the straight line formed by q and t(a, m); Predict the single - well recoverable reserves of an oil well under a specified number of years, and the formula is as follows: EUR = ∑q In the formula, EUR is the single - well recoverable reserves.

6. According to the device described in claim 5, characterized in that, the fracturing construction pumping parameters include: the viscosity, density and type of the fracturing fluid; the proportion of different types of fracturing fluids; the injection time and injection volume of different types of fracturing fluids; the density, size and type of the proppant; the injection volume of the proppant in different stages; after the pumping ends, stop the pump, and obtain the construction pressure drop data through on - site pressure statistics; In-situ geological parameters include: Young's modulus and Poisson's ratio of the target formation obtained from uniaxial compression tests.

7. The device according to claim 5, wherein, the whole-well imbibition energy-increasing volume processing module is specifically configured to: acquire bottom-hole flowing pressure data during the shut-in period, and draw a flow characteristic curve based on the bottom-hole flowing pressure data, wherein the characteristic curve includes a pressure drop curve and a pressure drop derivative curve; divide the shut-in pressure drop into nine flow stages according to the pressure drop curve and the pressure drop derivative curve, wherein the four flow stages under the control of the end-section fracture in the last stage, the four flow stages under the control of the whole-well section fracture, and the flow stage under the control of the matrix; wherein, the four flow stages under the control of the end-section fracture include: the first stage, the wellbore afterflow control stage, where the pressure drop curve and the pressure drop derivative curve coincide and the slope is 1; the second stage, the end extension stage, where the slope of the pressure drop derivative curve is 0; the third stage, the linear stage inside the fracture before closure, where the slope of the pressure drop derivative curve is 1 / 2; the fourth stage, the fracture closure control stage, where the slope of the pressure drop derivative curve is greater than 1 / 2; wherein, the four flow stages under the control of the whole-well section fracture include: the fifth stage, the end-section - front-section connection control stage, where the curve of the pressure drop derivative shows a negative slope; the sixth stage, the main fracture storage stage, where the curve of the pressure drop derivative shows a positive slope; the seventh stage, the crossflow control stage between the main and secondary fractures, where the curve of the pressure drop derivative shows a negative slope; the eighth stage, the secondary fracture storage stage, where the curve of the pressure drop derivative shows a positive slope; wherein, the flow stage under the control of the matrix is: the ninth stage, the matrix flow control stage, where the curve of the pressure drop derivative shows a negative slope until the pressure drop is zero; establish a pseudo-steady state flow mathematical model for the main and secondary fracture storage control: Main crack: Secondary crack: Among them where p i is the initial formation pressure, MPa; p w is the bottom-hole pressure, MPa; q m is the flow rate of the fracture into the matrix during the shut-in period, obtained by simulating the shut-in time based on the imbibition experiment law, m 3 / d; Q m is the cumulative flow rate of the fracture into the matrix during the shut-in period, m 3 ; B w is the volume coefficient of the fracturing fluid, m 3 / m 3 ; V ehf is the effective fracture volume of the main fracture, m 3 ; C hf is the compressibility of the main fracture, MPa -1 ; is the fracture porosity, in decimals; k f is the fracture permeability, mD; μ f is the viscosity of the fracturing fluid, mPa·s; L f is the half-length of the main fracture; C t is the compressibility of the rock, MPa -1 ; V esf is the effective fracture volume of the secondary fracture, m 3 ; C sf is the compressibility of the secondary fracture, MPa -1 ; C f is the comprehensive compressibility of the fracture; Through numerical simulation with reservoir simulation software, obtain the fluid leakage rate q from the fracture to the matrix during the shut-in period m and the cumulative fluid leakage volume Q from the fracture to the matrix during the shut-in period m ; Through fracture conductivity tests, obtain the primary fracture compressibility C hf and the secondary fracture compressibility C sf ; Obtain the fracturing fluid volume coefficient B by querying the oilfield data w ; When the bottom-hole flowing pressure data during the shut-in period is in the sixth stage, use the pressure drop data in the sixth stage to plot the characteristic curve of normalized pressure vs. material balance time in a rectangular coordinate system, where the normalized pressure is (p i - p w ) / q m , and the material balance time is Q m / q m ; obtain the slope value m f ; Based on the pseudo-steady state flow mathematical model controlled by the main fracture reservoir, it is obtained that Import the known C hf , and the effective volume V of the main fractures in the entire well section is obtained ehf as follows: When the bottom-hole flowing pressure data during the shut-in period is in the eighth stage, use the pressure drop data in the eighth stage to plot the characteristic curve of the normalized pressure and the material balance time in the rectangular coordinate system, where the normalized pressure is (p i - p w ) / q m , and the material balance time is Q m / q m ; obtain the slope value m F ; Based on the pseudo-steady state flow mathematical model controlled by secondary fracture storage, it is obtained that Import the known C sf , and the effective volume V of the secondary fracture is obtained esf as follows: Add the effective volume V of the main fractures in the entire well section ehf and the obtained effective volume V of the secondary fractures esf to get the total effective fracture volume V ef after fracturing in the entire well section, which is the imbibition energy-increasing volume of the entire well.

8. A computer device, wherein, it includes: at least one processor and a memory; the memory stores computer execution instructions; the at least one processor executes the computer execution instructions stored in the memory, so that the at least one processor executes the full-life cycle fracturing fracture volume evaluation processing according to any one of claims 1 to 4.

9. A computer-readable storage medium, wherein, the computer-readable storage medium stores computer execution instructions, and when the processor executes the computer execution instructions, the full-life cycle fracturing fracture volume evaluation processing according to any one of claims 1 to 4 is realized.

Images