CN111396013A - Method and device for determining shale gas well fracturing modification scheme and storage medium - Google Patents

Method and device for determining shale gas well fracturing modification scheme and storage medium Download PDF

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CN111396013A
CN111396013A CN202010162574.4A CN202010162574A CN111396013A CN 111396013 A CN111396013 A CN 111396013A CN 202010162574 A CN202010162574 A CN 202010162574A CN 111396013 A CN111396013 A CN 111396013A
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田冲
蒋鑫
吴伟
常程
季春海
罗超
吴天鹏
刘文平
李度
刘军
赵圣贤
张成林
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Abstract

The application discloses a method and a device for determining a shale gas well fracturing modification scheme and a storage medium, and belongs to the technical field of oil and gas exploitation. The method comprises the following steps: acquiring the formation temperature, the gas deviation coefficient, the initial formation pressure, the production formation pressure and the accumulated gas production rate of each gas well in a plurality of gas wells, and the landform volume, the landform pressure, the porosity, the water saturation, the density and the adsorbed methane density of a shale reservoir corresponding to each gas well; determining the initial gas content and the residual gas content of each gas well; determining the fracture modification volume of each gas well; and selecting one gas well with the largest fracturing modification volume from the plurality of gas wells, and determining the fracturing modification scheme of the selected gas well as the fracturing modification scheme of the shale gas well. The fracturing modification volume of each gas well determined through actual production data is accurate and objective data, so that a more optimized fracturing modification scheme of the shale gas well can be determined.

Description

Method and device for determining shale gas well fracturing modification scheme and storage medium
Technical Field
The application relates to the technical field of oil and gas exploitation, in particular to a method and a device for determining a shale gas well fracturing modification scheme and a storage medium.
Background
Shale gas is an unconventional natural gas resource, and related development process technology gradually matures. Because the shale gas well fracturing modification scheme plays a decisive role in the development of shale gas, in order to realize the full development of shale gas, a most effective fracturing modification scheme can be determined. Generally, the fracture modification volume of the shale gas well can be a main means for evaluating the quality of a fracture modification scheme, so that the optimal fracture modification scheme can be selected by calculating the fracture modification volume of the shale gas well.
In the related art, a microseism monitoring method is mainly used for calculating the fracture modification volume of the shale gas well. In the fracturing process of the shale gas well, the earthquake response points at the fracturing positions are monitored through the surface monitor, so that a three-dimensional position diagram of the earthquake response points can be generated, and the fracturing modification volume of the shale gas well can be calculated based on position data in the three-dimensional position diagram.
However, part of the seismic response points are in communication with the wellbore from which shale gas is produced, and part of the seismic response points are seismic response points from the formation adjacent the wellbore that are squeezed and are not in communication with the wellbore. However, seismic response points communicating with the wellbore cannot be identified, and therefore accuracy of the calculation results is affected. In addition, the sensitivity of the surface monitor is limited, so that seismic response points with weak signals cannot be monitored, and the accuracy of a calculation result is also influenced. Therefore, the selected fracturing modification scheme of the shale gas well cannot be ensured to be the optimal fracturing modification scheme.
Disclosure of Invention
The application provides a method, a device and a storage medium for determining a fracturing modification scheme of a shale gas well, and can solve the problem that the optimal fracturing modification scheme of the shale gas well cannot be determined due to inaccurate fracturing modification volume calculation result. The technical scheme is as follows:
in a first aspect, a method for determining a shale gas well fracturing modification scheme is provided, and the method comprises the following steps:
the method comprises the steps of obtaining the formation temperature, the gas deviation coefficient, the initial formation pressure, the production formation pressure and the accumulated gas yield of each gas well in a plurality of gas wells, and the landform volume, the landform pressure, the porosity, the water saturation, the density and the adsorption methane density of a shale reservoir layer corresponding to each gas well, wherein the plurality of gas wells are produced by adopting different fracturing modification schemes respectively, and the production formation pressure and the accumulated gas yield refer to the production formation pressure and the accumulated gas yield of the gas wells after a period of time;
determining the initial gas content and the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient, the initial formation pressure and the production formation pressure of each gas well, and the Lanzhou volume, Lanzhou pressure, porosity, water saturation, density and adsorption methane density of a shale reservoir corresponding to each gas well;
determining the fracturing modification volume of each gas well based on the initial gas content, the residual gas content, the accumulated gas yield and the corresponding density of the shale reservoir;
displaying the fracturing modification scheme and the fracturing modification volume of each gas well in the plurality of gas wells;
and selecting one gas well with the largest fracturing modification volume from the plurality of gas wells, and determining the fracturing modification scheme of the selected gas well as the fracturing modification scheme of the shale gas well.
Optionally, the determining the initial gas content and the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient, the initial formation pressure and the production formation pressure of each gas well, and the landform volume, the landform pressure, the porosity, the water saturation, the density and the methane density in an adsorption state of the shale reservoir corresponding to each gas well comprises:
determining the initial gas content of each gas well based on the formation temperature, the gas deviation coefficient and the initial formation pressure of each gas well, and the Lanzhou volume, Lanzhou pressure, porosity, water saturation, density and adsorption methane density of the shale reservoir corresponding to each gas well;
and determining the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient and the production formation pressure of each gas well, and the Lange volume, Lange pressure, porosity, water saturation, density and adsorbed methane density of the shale reservoir corresponding to each gas well.
Optionally, the determining the initial gas content of each gas well based on the formation temperature, the gas deviation coefficient and the initial formation pressure of each gas well, and the landform volume, the landform pressure, the porosity, the water saturation, the density and the adsorbed methane density of the shale reservoir corresponding to each gas well comprises:
determining the initial adsorption gas volume of each gas well according to a first relational expression based on the initial formation pressure of each gas well and the Lanzhou volume and Lanzhou pressure of the shale reservoir corresponding to each gas well;
wherein the first relation is:
Figure BDA0002406312830000031
wherein, VLIs a blue volume, PLIs a blue pressure, P is a pressure, VadsFor adsorbing gas, when P is the initial formation pressure, VadsThe initial adsorption gas amount;
determining the initial free gas quantity of each gas well according to a second relational expression based on the initial formation pressure, the initial adsorbed gas quantity, the formation temperature and the gas deviation coefficient of each gas well as the porosity, the water saturation, the density and the adsorbed methane density of the shale reservoir corresponding to each gas well;
wherein the second relation is:
Figure BDA0002406312830000032
wherein the content of the first and second substances,
Figure BDA0002406312830000033
porosity of shale reservoir, SWWater saturation of shale reservoir, VadsTo adsorb the gas quantity, ρrockDensity of shale reservoir, MCH4Amount of substance which is methane, VCH4Molar volume of methane in standard conditions, padsAdsorbed methane density, T, for shale reservoirs0Is the formation temperature, Z0Is a gas deviation coefficient, PSCFor pressure under standard conditions, TSCIs the temperature at standard conditions, P is the pressure, VfreeIs the amount of free gas, V is when P is the initial formation pressureadsIs the initial adsorbed gas quantity, VfreeThe initial free gas amount;
and determining the sum of the initial free gas quantity and the initial adsorbed gas quantity of each gas well as the initial gas content of each gas well.
Optionally, the determining a fracture modification volume of each gas well based on the initial gas content, the residual gas content, the cumulative gas production and the density of the corresponding shale reservoir of each gas well comprises:
determining the difference value between the initial gas content and the residual gas content of each gas well to obtain the gas content difference value of each gas well;
and determining the fracturing modification volume of each gas well based on the gas content difference value of each gas well, the accumulated gas production and the density of the corresponding shale reservoir.
Optionally, the determining a fracture modification volume of each gas well based on the gas content difference, the cumulative gas production and the density of the corresponding shale reservoir of each gas well includes:
determining the fracturing modification volume of each gas well according to the following third relation formula based on the gas content difference value, the accumulated gas production rate and the density of the corresponding shale reservoir;
wherein the third relation is:
Figure BDA0002406312830000034
wherein SRV is the fracture reconstruction volume, Q1For cumulative gas production, △ V is the difference in gas content, ρrockIs the density of the shale reservoir.
In a second aspect, there is provided an apparatus for determining a shale gas well fracture reformation scheme, the apparatus comprising: an acquisition module: the method comprises the steps of obtaining the formation temperature, the gas deviation coefficient, the initial formation pressure, the production formation pressure and the accumulated gas yield of each gas well in a plurality of gas wells, and the landform volume, the landform pressure, the porosity, the water saturation, the density and the adsorption methane density of a shale reservoir layer corresponding to each gas well, wherein the plurality of gas wells are produced by adopting different fracturing modification schemes respectively, and the production formation pressure and the accumulated gas yield refer to the production formation pressure and the accumulated gas yield of the gas wells after a period of time;
a first determination module: determining the initial gas content and the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient, the initial formation pressure and the production formation pressure of each gas well, and the Lanzhou volume, Lanzhou pressure, porosity, water saturation, density and adsorption methane density of a shale reservoir corresponding to each gas well;
a second determination module: determining the fracturing modification volume of each gas well based on the initial gas content, the residual gas content, the accumulated gas yield and the corresponding density of the shale reservoir;
a display module: displaying the fracturing modification scheme and the fracturing modification volume of each gas well in the plurality of gas wells;
a third determination module: and selecting one gas well with the largest fracturing modification volume from the plurality of gas wells, and determining the fracturing modification scheme of the selected gas well as the fracturing modification scheme of the shale gas well.
Optionally, the first determining module includes:
a first determination unit: determining the initial gas content of each gas well based on the formation temperature, the gas deviation coefficient and the initial formation pressure of each gas well, and the Lanzhou volume, Lanzhou pressure, porosity, water saturation, density and adsorption methane density of the shale reservoir corresponding to each gas well;
a second determination unit: and determining the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient and the production formation pressure of each gas well, and the Lange volume, Lange pressure, porosity, water saturation, density and adsorbed methane density of the shale reservoir corresponding to each gas well.
Optionally, the first determining unit includes:
a first determining subunit: determining the initial adsorption gas volume of each gas well according to a first relational expression based on the initial formation pressure of each gas well and the Lanzhou volume and Lanzhou pressure of the shale reservoir corresponding to each gas well;
wherein the first relation is:
Figure BDA0002406312830000051
wherein, VLIs a blue volume, PLIs a blue pressure, P is a pressure, VadsFor adsorbing gas, when P is the initial formation pressure, VadsThe initial adsorption gas amount;
a second determination subunit: determining the initial free gas quantity of each gas well according to a second relational expression based on the initial formation pressure, the initial adsorbed gas quantity, the formation temperature and the gas deviation coefficient of each gas well as the porosity, the water saturation, the density and the adsorbed methane density of the shale reservoir corresponding to each gas well;
wherein the second relation is:
Figure BDA0002406312830000052
wherein the content of the first and second substances,
Figure BDA0002406312830000053
porosity of shale reservoir, SWWater saturation of shale reservoir, VadsTo adsorb the gas quantity, ρrockDensity of shale reservoir, MCH4Amount of substance which is methane, VCH4Molar volume of methane in standard conditions, padsAdsorbed methane density, T, for shale reservoirs0Is the formation temperature, Z0Is a gas deviation coefficient, PSCFor pressure under standard conditions, TSCIs the temperature at standard conditions, P is the pressure, VfreeIs the amount of free gas, V is when P is the initial formation pressureadsIs the initial adsorbed gas quantity, VfreeThe initial free gas amount;
a third determining subunit: and determining the sum of the initial free gas quantity and the initial adsorbed gas quantity of each gas well as the initial gas content of each gas well.
Optionally, the second determining module includes:
a third determination unit: determining the difference value between the initial gas content and the residual gas content of each gas well to obtain the gas content difference value of each gas well;
a fourth determination unit: and determining the fracturing modification volume of each gas well based on the gas content difference value of each gas well, the accumulated gas production and the density of the corresponding shale reservoir.
Optionally, the fourth determining unit includes:
a fourth determination subunit: determining the fracturing modification volume of each gas well according to the following third relation formula based on the gas content difference value, the accumulated gas production rate and the density of the corresponding shale reservoir;
wherein the third relation is:
Figure BDA0002406312830000054
wherein SRV is the fracture reconstruction volume, Q1For cumulative gas production, △ V is the difference in gas content, ρrockIs the density of the shale reservoir.
In a third aspect, a computer-readable storage medium is provided, in which a computer program is stored, which, when executed by a processor, implements any of the methods provided in the first aspect above.
In a fourth aspect, there is provided a computer program product containing instructions which, when run on a computer, cause the computer to perform the method of determining a shale gas well frac modification scenario provided in the first aspect.
The beneficial effects that technical scheme that this application provided brought can include at least:
because the initial gas content, the residual gas content and the accumulated gas yield of each gas well are actual production data of the shale gas well, the determined fracturing modification volume of each gas well is accurate and objective data based on the initial gas content, the residual gas content, the accumulated gas yield and the corresponding density of the shale reservoir. Therefore, accurate comparison of the fracturing modification volumes of the multiple gas wells is facilitated, and a more optimized shale gas well fracturing modification scheme can be determined.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings needed to be used in the description of the embodiments are briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present application, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.
FIG. 1 is a schematic flow chart of a method for determining a shale gas well fracturing modification scenario, provided by an embodiment of the present application;
FIG. 2 is a schematic flow chart of another shale gas well fracturing modification scenario determination method provided by an embodiment of the application;
FIG. 3 is a schematic structural diagram of a shale gas well fracturing reformation scheme determination device provided by an embodiment of the application;
fig. 4 is a schematic structural diagram of a terminal according to an embodiment of the present application.
Detailed Description
To make the objects, technical solutions and advantages of the present application more clear, embodiments of the present application will be described in further detail below with reference to the accompanying drawings.
Fig. 1 is a schematic flow chart of a method for determining a shale gas well fracturing reformation scheme provided by an embodiment of the application. The method is applied to the terminal, and the terminal can be a smart phone, a tablet computer, a notebook computer or a desktop computer and the like. Referring to fig. 1, the method includes the following steps.
Step 101: the method comprises the steps of obtaining the formation temperature, the gas deviation coefficient, the initial formation pressure, the production formation pressure and the accumulated gas production rate of each gas well in the multiple gas wells, and the Lanzhou volume, the Lanzhou pressure, the porosity, the water saturation, the density and the adsorption methane density of a shale reservoir layer corresponding to each gas well, wherein the multiple gas wells are produced by adopting different fracturing transformation schemes, and the production formation pressure and the accumulated gas production rate refer to the production formation pressure and the accumulated gas production rate of the gas wells after a period of gas well production.
Step 102: and determining the initial gas content and the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient, the initial formation pressure and the production formation pressure of each gas well, and the Lanzhou volume, Lanzhou pressure, porosity, water saturation, density and methane density in an adsorption state of the shale reservoir corresponding to each gas well.
Step 103: and determining the fracture modification volume of each gas well based on the initial gas content, the residual gas content, the accumulated gas production and the corresponding density of the shale reservoir of each gas well.
Step 104: and displaying the fracturing modification scheme and the fracturing modification volume of each gas well in the plurality of gas wells.
Step 105: and selecting one gas well with the largest fracturing modification volume from the plurality of gas wells, and determining the fracturing modification scheme of the selected gas well as the fracturing modification scheme of the shale gas well.
In the embodiment of the application, because the initial gas content, the residual gas content and the accumulated gas yield of each gas well are actual production data of shale gas wells, the determined fracturing modification volume of each gas well is accurate and objective data based on the initial gas content, the residual gas content, the accumulated gas yield and the corresponding density of a shale reservoir. Therefore, accurate comparison of the fracturing modification volumes of the multiple gas wells is facilitated, and a more optimized shale gas well fracturing modification scheme can be determined.
Optionally, determining the initial gas content and the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient, the initial formation pressure and the production formation pressure of each gas well, and the landform volume, the landform pressure, the porosity, the water saturation, the density and the methane density in an adsorption state of the shale reservoir corresponding to each gas well comprises:
determining the initial gas content of each gas well based on the formation temperature, the gas deviation coefficient and the initial formation pressure of each gas well, and the Lanzhou volume, Lanzhou pressure, porosity, water saturation, density and adsorption methane density of the shale reservoir corresponding to each gas well;
and determining the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient and the production formation pressure of each gas well, and the Lange volume, Lange pressure, porosity, water saturation, density and adsorbed methane density of the shale reservoir corresponding to each gas well.
Optionally, determining the initial gas content of each gas well based on the formation temperature, the gas deviation coefficient and the initial formation pressure of each gas well, and the landform volume, the landform pressure, the porosity, the water saturation, the density and the adsorbed methane density of the shale reservoir corresponding to each gas well, comprises:
determining the initial adsorption gas volume of each gas well according to a first relational expression based on the initial formation pressure of each gas well and the Lanzhou volume and Lanzhou pressure of the shale reservoir corresponding to each gas well;
wherein the first relational expression is:
Figure BDA0002406312830000081
wherein, VLIs a blue volume, PLIs a blue pressure, P is a pressure, VadsFor adsorbing gas, when P is the initial formation pressure, VadsThe initial adsorption gas amount;
determining the initial free gas quantity of each gas well according to a second relational expression based on the initial formation pressure, the initial adsorbed gas quantity, the formation temperature and the gas deviation coefficient of each gas well as the porosity, the water saturation, the density and the adsorbed methane density of the shale reservoir corresponding to each gas well;
wherein the second relation is:
Figure BDA0002406312830000082
wherein the content of the first and second substances,
Figure BDA0002406312830000083
porosity of shale reservoir, SWWater saturation of shale reservoir, VadsTo adsorb the gas quantity, ρrockDensity of shale reservoir, MCH4Amount of substance which is methane, VCH4Molar volume of methane in standard conditions, padsAdsorbed methane density, T, for shale reservoirs0Is the formation temperature, Z0Is a gas deviation coefficient, PSCFor pressure under standard conditions, TSCIs the temperature at standard conditions, P is the pressure, VfreeIs the amount of free gas, V is when P is the initial formation pressureadsIs the initial adsorbed gas quantity, VfreeThe initial free gas amount;
and determining the sum of the initial free gas quantity and the initial adsorbed gas quantity of each gas well as the initial gas content of each gas well.
Optionally, determining the fracture modification volume of each gas well based on the initial gas content, the residual gas content, the cumulative gas production and the density of the corresponding shale reservoir of each gas well, comprises:
determining the difference value between the initial gas content and the residual gas content of each gas well to obtain the gas content difference value of each gas well;
and determining the fracturing modification volume of each gas well based on the gas content difference value of each gas well, the accumulated gas production and the density of the corresponding shale reservoir.
Optionally, determining a fracture modification volume of each gas well based on the gas content difference of each gas well, the cumulative gas production and the density of the corresponding shale reservoir, including:
determining the fracturing modification volume of each gas well according to the following third relation formula based on the gas content difference value, the accumulated gas production rate and the density of the corresponding shale reservoir;
wherein the third relation is:
Figure BDA0002406312830000091
wherein SRV is the fracture reconstruction volume, Q1For cumulative gas production, △ V is the difference in gas content, ρrockIs the density of the shale reservoir.
All the above optional technical solutions can be combined arbitrarily to form an optional embodiment of the present application, and the present application embodiment is not described in detail again.
Fig. 2 is a schematic flow chart of a method for determining a shale gas well fracturing reformation scheme provided by an embodiment of the application. The method is applied to the terminal, and the terminal can be a smart phone, a tablet computer, a notebook computer or a desktop computer and the like. Referring to fig. 2, the method includes the following steps.
In the process of determining the fracturing modification scheme of the shale gas well, the fracturing modification volume of the shale gas well can be a main means for evaluating the quality of one fracturing modification scheme, so that the optimal fracturing modification scheme can be selected by calculating the fracturing modification volumes of a plurality of gas wells. For multiple gas wells, the fracture modification volume for each gas well may be determined as follows from step 201 to step 204.
It should be noted that a gas well may be a well developed in a shale reservoir during actual production; shale gas wells may be a type of well developed in shale reservoirs.
Step 201: and acquiring the formation temperature, the gas deviation coefficient, the initial formation pressure, the production formation pressure and the accumulated gas production rate of each gas well in the plurality of gas wells, and the landform volume, the landform pressure, the porosity, the water saturation, the density and the adsorbed methane density of the shale reservoir corresponding to each gas well.
The gas wells are produced by adopting different fracturing modification schemes, and the produced formation pressure and the accumulated gas production rate refer to the produced formation pressure and the accumulated gas production rate of the gas wells after a period of gas well production.
In some embodiments, the terminal may display the parameter obtaining interface, and then the terminal may obtain the formation temperature, the gas deviation coefficient, the initial formation pressure, the production formation pressure and the accumulated gas production rate of each gas well, which are input in the parameter obtaining interface by the user, and the landform volume, the landform pressure, the porosity, the water saturation, the density and the methane density in an adsorption state of the shale reservoir corresponding to each gas well. That is, the user may input the formation temperature, the gas deviation coefficient, the initial formation pressure, the productive formation pressure, and the cumulative gas production rate of each gas well, and the landform volume, the landform pressure, the porosity, the water saturation, the density, and the adsorbed methane density of the shale reservoir corresponding to each gas well in the parameter obtaining interface. Thus, the terminal can acquire the parameters from the parameter acquisition interface. Of course, the terminal may also communicate with a storage device for such data to retrieve such data from the storage device. The embodiment of the present application does not limit this.
The initial formation pressure can be the formation pressure of the shale gas well after fracturing transformation and before formal gas production. The initial formation pressure may be determined based on the following three methods.
The method comprises the steps of obtaining a plurality of initial times and a plurality of initial pressure values corresponding to the initial times one by one, and generating a curve graph of the initial times and the initial pressures. Therefore, the initial pressure value corresponding to the initial time approaching infinity can be simulated based on the generated curve graph, and the initial pressure value can be determined as the initial formation pressure. And detecting the initial time and the initial pressure values after slight fracturing is generated in the shale gas well and the shale gas well is in a stuffy well state.
And secondly, obtaining a well depth value, water density, a gravity proportion coefficient and well head pressure. And the wellhead pressure is the pressure detected after the fracturing modification of the shale gas well is completed and the well is closed for a period of time until the wellhead pressure is stable. And further determining the initial formation pressure according to a fifth relation based on the well depth value, the water density, the gravity proportionality coefficient and the well head pressure as follows:
P0＝Pwell+ρWater (W)gHWell
Wherein, P0To initial formation pressure, PWellIs the wellhead pressure, ρWater (W)Is the density of water, g is the gravity proportionality coefficient, HWellIs a well depth value.
And thirdly, acquiring a pressure value detected by a pressure gauge arranged on the gas well, and determining the pressure value as the initial formation pressure. The pressure value can be a pressure value detected after the shale gas well fracturing transformation is completed and the well is closed for a period of time, and the well mouth is opened to enable liquid in the well to be discharged and the well is closed.
Wherein the formation temperature and cumulative gas production for each gas well may be determined based on field testing. The shale gas components, the initial formation pressure and the formation temperature can be obtained, and based on the shale gas components, the initial formation pressure and the formation temperature, according to GB/T35210.1-2017, part I of shale methane isothermal adsorption determination method: the correlation formula in the volume method determines the gas deviation coefficient. The method can acquire a plurality of mining times and a plurality of mining pressure values corresponding to the mining times one to one, and determine the production formation pressure according to a relevant formula in the pressure recovery well testing data based on the mining times and the mining pressure values. And the plurality of mining time and the plurality of mining pressure values which are in one-to-one correspondence with the plurality of mining time are the time and the pressure values detected after the shale gas well is closed for 10 days after fracturing reformation and production is completed for a period of time. Based on a sample analysis experiment and GB/T35210.1-2017, the first part of the isothermal adsorption determination method for shale methane can be obtained: relevant provisions in the volumetric law determine the Lane volume, Lane pressure, porosity, water saturation, density and adsorbed methane density.
After obtaining the above parameters, the initial gas content and the residual gas content of each gas well can be determined based on the formation temperature, the gas deviation coefficient, the initial formation pressure and the production formation pressure of each gas well, and the landform volume, the landform pressure, the porosity, the water saturation, the density and the adsorbed methane density of the shale reservoir corresponding to each gas well. In some embodiments, the initial gas content and the remaining gas content of each gas well may be determined by steps 202-203 as follows.
Step 202: and determining the initial gas content of each gas well based on the formation temperature, the gas deviation coefficient and the initial formation pressure of each gas well, and the Lange volume, Lange pressure, porosity, water saturation, density and adsorbed methane density of the shale reservoir corresponding to each gas well.
Next, the process of determining the initial gas content of each gas well will be described in detail. In some embodiments, the initial gas content of each gas well may be determined as follows in steps (1) - (3).
(1) And determining the initial adsorption gas volume of each gas well according to a first relational expression based on the initial formation pressure of each gas well, and the Lange volume and Lange pressure of the shale reservoir corresponding to each gas well.
Wherein the first relational expression is:
Figure BDA0002406312830000111
wherein, VLIs a blue volume in cm3/g；PLIs the Lange pressure in MPa; p is pressure, the unit is MPa, and when the initial adsorption gas amount is determined, P can be the initial formation pressure; vadsIs the amount of adsorbed gas in cm3V,/g, when P is the initial formation pressureadsThe initial amount of adsorbed gas.
(2) And determining the initial free gas quantity of each gas well according to a second relational expression based on the initial formation pressure, the initial adsorbed gas quantity, the formation temperature and the gas deviation coefficient of each gas well, and the porosity, the water saturation, the density and the adsorbed methane density of the shale reservoir corresponding to each gas well.
Wherein the second relation is:
Figure BDA0002406312830000112
wherein the content of the first and second substances,
Figure BDA0002406312830000113
porosity of the shale reservoir; sWThe water saturation of the shale reservoir; vadsIs the amount of adsorbed gas in cm3/g，VadsThe determination may be made in accordance with a first relationship; rhorockIs the density of the shale reservoir and has the unit of g/cm3；MCH4The amount of material that is methane in g/mol; vCH4Is the molar volume of methane under standard conditions and has the unit of L/mol and rhoadsIs the density of methane in the shale reservoir in the adsorption state with the unit of g/cm3；T0Is the formation temperature in units of; z0Is the gas deviation coefficient; pSCIn order to provide a pressure under standard conditions,the unit is MPa; t isSCIs the temperature under standard conditions in units of ℃; p is pressure, the unit is MPa, and when the initial free gas amount is determined, P can be the initial formation pressure; vfreeIs free gas amount in cm3V,/g, when P is the initial formation pressureadsIs the initial adsorbed gas quantity, VfreeThe initial amount of free gas.
(3) And determining the sum of the initial free gas quantity and the initial adsorbed gas quantity of each gas well as the initial gas content of each gas well.
It should be noted that the shale gas may exist in the shale reservoir in both a free state and an adsorbed state, and thus when determining the initial gas content, the initial free gas content and the initial adsorbed gas content of each gas well may be added and summed to determine the initial gas content of each gas well.
It should be further noted that, in addition to determining the initial gas content of each gas well through the steps (1) - (3) above, the initial gas content of each gas well may also be determined directly through the following fourth relational expression based on the initial formation pressure, the initial adsorbed gas amount of each gas well, the landform volume, the landform pressure, the formation temperature and the gas deviation coefficient of the shale reservoir corresponding to each gas well, and the porosity, the water saturation, the density and the methane density in an adsorbed state of the shale reservoir corresponding to each gas well.
Wherein the fourth relation is:
Figure BDA0002406312830000121
wherein, VtotalIs the gas content in cm3V,/g, when P is the initial formation pressureadsIs the initial adsorbed gas quantity, VtotalIs the initial gas content. For the detailed meanings of other parameters in the fourth relational expression, reference may be made to the meanings of the same parameters in the first relational expression and the second relational expression, which are not described in detail in this embodiment of the application.
Step 203: and determining the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient and the production formation pressure of each gas well, and the Lange volume, Lange pressure, porosity, water saturation, density and adsorbed methane density of the shale reservoir corresponding to each gas well.
It should be noted that the detailed process for determining the residual gas content of each gas well may be similar to the steps (1) - (3), and details thereof are not repeated in this embodiment of the present application. When P in the first relation is a production formation pressure, VadsThe residual adsorption gas amount is used; when P in the second relation is production formation pressure, VadsIs the residual adsorption gas quantity, VfreeThe residual free gas amount is; when P in the fourth relation is a production formation pressure, VadsIs the residual adsorption gas quantity, VtotalIs the residual gas content.
Step 204: and determining the fracture modification volume of each gas well based on the initial gas content, the residual gas content, the accumulated gas production and the corresponding density of the shale reservoir of each gas well.
Next, a process of determining the fracture modification volume of each gas well will be described in detail. In some embodiments, the fracture modification volume for each gas well may be determined as follows in steps (1) - (2).
(1) And determining the difference value between the initial gas content and the residual gas content of each gas well to obtain the gas content difference value of each gas well.
In some embodiments, the difference between the initial gas content and the residual gas content of each gas well may be determined based on the initial gas content and the residual gas content of each gas well, and the gas content difference of each gas well may be obtained.
(2) And determining the fracturing modification volume of each gas well according to the following third relation formula based on the gas content difference value, the accumulated gas production and the density of the corresponding shale reservoir.
Wherein the third relation is:
Figure BDA0002406312830000131
wherein, SRV is the volume of fracturing reconstructionBit is m3；Q1For cumulative gas production, in m3△ V is the difference of gas content, and the unit is m3/t；ρrockIs the density of the shale reservoir and has the unit of g/cm3。
Step 205: and displaying the fracturing modification scheme and the fracturing modification volume of each gas well in the plurality of gas wells.
The terminal can obtain a plurality of fracturing modification schemes corresponding to the plurality of gas wells, and display the plurality of fracturing modification schemes and a plurality of fracturing modification volumes corresponding to each fracturing modification scheme on the basis of the obtained plurality of fracturing modification schemes and the fracturing modification volume of each gas well calculated in the step (2) in the step 204.
The fracturing transformation scheme comprises the injection amount of fracturing fluid, the construction discharge amount of the fracturing fluid, the increment of proppant, the number and the length of sections of a horizontal well, the sand injection amount and the like. In addition, the fracture modification scheme may also include other contents, such as a fracturing mode, and the like, and reference may be made to related technologies specifically, which is not limited in the embodiments of the present application.
It should be noted that parameters such as the injection amount of the fracturing fluid, the construction displacement of the fracturing fluid, the increment of the proppant, the number of sections and the length of the sections of the horizontal well, and the sand injection amount in different fracturing modification schemes may be different.
Step 206: and selecting one gas well with the largest fracturing modification volume from the plurality of gas wells, and determining the fracturing modification scheme of the selected gas well as the fracturing modification scheme of the shale gas well.
In some embodiments, the plurality of fracture modification volumes may be compared and arranged based on the numerical values of the plurality of fracture modification volumes, and the fracture modification volume having the largest numerical value may be determined, so that one gas well corresponding to the fracture modification volume may be determined. In this way, the fracturing modification scheme corresponding to the gas well can be determined as the fracturing modification scheme of the shale gas well.
In the embodiment of the application, because the initial gas content, the residual gas content and the accumulated gas yield of each gas well are actual production data of shale gas wells, the determined fracturing modification volume of each gas well is accurate and objective data based on the initial gas content, the residual gas content, the accumulated gas yield and the corresponding density of a shale reservoir. Therefore, accurate comparison of the fracturing modification volumes of the multiple gas wells is facilitated, and a more optimized shale gas well fracturing modification scheme can be determined.
Fig. 3 is a schematic structural diagram of a determination device for a shale gas well fracturing reformation scheme provided by an embodiment of the application. Referring to fig. 3, the apparatus includes:
the acquisition module 301: the method comprises the steps of obtaining the formation temperature, the gas deviation coefficient, the initial formation pressure, the production formation pressure and the accumulated gas production rate of each gas well in the multiple gas wells, and the Lanzhou volume, the Lanzhou pressure, the porosity, the water saturation, the density and the adsorption methane density of a shale reservoir layer corresponding to each gas well, wherein the multiple gas wells are produced by adopting different fracturing transformation schemes, and the production formation pressure and the accumulated gas production rate refer to the production formation pressure and the accumulated gas production rate of the gas wells after a period of gas well production.
The first determination module 302: and determining the initial gas content and the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient, the initial formation pressure and the production formation pressure of each gas well, and the Lanzhou volume, Lanzhou pressure, porosity, water saturation, density and methane density in an adsorption state of the shale reservoir corresponding to each gas well.
The second determination module 303: and determining the fracture modification volume of each gas well based on the initial gas content, the residual gas content, the accumulated gas production and the corresponding density of the shale reservoir of each gas well.
The display module 304: and displaying the fracturing modification scheme and the fracturing modification volume of each gas well in the plurality of gas wells.
The third determination module 305: and selecting one gas well with the largest fracturing modification volume from the plurality of gas wells, and determining the fracturing modification scheme of the selected gas well as the fracturing modification scheme of the shale gas well.
Optionally, the first determining module 302 includes:
a first determination unit: and determining the initial gas content of each gas well based on the formation temperature, the gas deviation coefficient and the initial formation pressure of each gas well, and the Lange volume, Lange pressure, porosity, water saturation, density and adsorbed methane density of the shale reservoir corresponding to each gas well.
A second determination unit: and determining the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient and the production formation pressure of each gas well, and the Lange volume, Lange pressure, porosity, water saturation, density and adsorbed methane density of the shale reservoir corresponding to each gas well.
Optionally, the first determination unit includes:
a first determining subunit: determining the initial adsorption gas volume of each gas well according to a first relational expression based on the initial formation pressure of each gas well and the Lanzhou volume and Lanzhou pressure of the shale reservoir corresponding to each gas well;
wherein the first relational expression is:
Figure BDA0002406312830000151
wherein, VLIs a blue volume, PLIs a blue pressure, P is a pressure, VadsFor adsorbing gas, when P is the initial formation pressure, VadsThe initial amount of adsorbed gas.
A second determination subunit: determining the initial free gas quantity of each gas well according to a second relational expression based on the initial formation pressure, the initial adsorbed gas quantity, the formation temperature and the gas deviation coefficient of each gas well as the porosity, the water saturation, the density and the adsorbed methane density of the shale reservoir corresponding to each gas well;
wherein the second relation is:
Figure BDA0002406312830000152
wherein the content of the first and second substances,
Figure BDA0002406312830000153
porosity of shale reservoir, SWWater saturation of shale reservoir, VadsTo adsorb the gas quantity, ρrockDensity of shale reservoir, MCH4Amount of substance which is methane, VCH4Molar volume of methane in standard conditions, padsAdsorbed methane density, T, for shale reservoirs0Is the formation temperature, Z0Is a gas deviation coefficient, PSCFor pressure under standard conditions, TSCIs the temperature at standard conditions, P is the pressure, VfreeIs the amount of free gas, V is when P is the initial formation pressureadsIs the initial adsorbed gas quantity, VfreeThe initial amount of free gas.
A third determining subunit: and determining the sum of the initial free gas quantity and the initial adsorbed gas quantity of each gas well as the initial gas content of each gas well.
Optionally, the second determining module 303 includes:
a third determination unit: and determining the difference between the initial gas content and the residual gas content of each gas well to obtain the gas content difference of each gas well.
A fourth determination unit: and determining the fracturing modification volume of each gas well based on the gas content difference value of each gas well, the accumulated gas production and the density of the corresponding shale reservoir.
Optionally, the fourth determining unit includes:
a fourth determination subunit: determining the fracturing modification volume of each gas well according to the following third relation formula based on the gas content difference value, the accumulated gas production rate and the density of the corresponding shale reservoir;
wherein the third relation is:
Figure BDA0002406312830000161
wherein SRV is the fracture reconstruction volume, Q1For cumulative gas production, △ V is the difference in gas content, ρrockIs the density of the shale reservoir.
In the embodiment of the application, because the initial gas content, the residual gas content and the accumulated gas yield of each gas well are actual production data of shale gas wells, the determined fracturing modification volume of each gas well is accurate and objective data based on the initial gas content, the residual gas content, the accumulated gas yield and the corresponding density of a shale reservoir. Therefore, accurate comparison of the fracturing modification volumes of the multiple gas wells is facilitated, and a more optimized shale gas well fracturing modification scheme can be determined.
It should be noted that: when the determining device for the shale gas well fracturing modification scheme provided by the embodiment determines the shale gas well fracturing modification scheme, the division of the functional modules is only used for illustration, and in practical application, the function distribution can be completed by different functional modules according to needs, that is, the internal structure of the equipment is divided into different functional modules so as to complete all or part of the functions described above. In addition, the determining device of the shale gas well fracturing modification scheme provided by the embodiment and the determining method of the shale gas well fracturing modification scheme provided by the embodiment belong to the same concept, and the specific implementation process is detailed in the method embodiment and is not described herein again.
Fig. 4 illustrates a block diagram of a terminal 400 according to an exemplary embodiment of the present application. Referring to fig. 4, the terminal 400 may be: a smartphone, a tablet, a laptop, or a desktop computer. The terminal 400 may also be referred to by other names such as user equipment, portable terminal, laptop terminal, desktop terminal, etc. Referring to fig. 4, the terminal 400 may include a processor 401 and a memory 402.
Processor 401 may include one or more Processing cores, such as a 4-core processor, an 8-core processor, etc. processor 401 may be implemented in at least one hardware form of a DSP (Digital Signal Processing), an FPGA (Field-Programmable Gate Array), a P L a (Programmable logic Array), processor 401 may also include a main processor and a coprocessor, the main processor being a processor for Processing data in a wake-up state, also known as a CPU (Central Processing Unit), the coprocessor being a low-power processor for Processing data in a standby state, in some embodiments, processor 401 may be integrated with a GPU (Graphics Processing Unit) for rendering and rendering content for display, in some embodiments, processor 401 may also include an AI (intelligent processor) for learning operations related to an AI (Artificial Intelligence processor) for computing operations related to display screens.
Memory 402 may include one or more computer-readable storage media, which may be non-transitory. Memory 402 may also include high speed random access memory, as well as non-volatile memory, such as one or more magnetic disk storage devices, flash memory storage devices. In some embodiments, a non-transitory computer readable storage medium in memory 402 is used to store at least one instruction for execution by processor 401 to implement a method of determining a shale gas well fracture modification scenario provided by method embodiments herein.
In some embodiments, the terminal 400 may further optionally include: a peripheral interface 403 and at least one peripheral. The processor 401, memory 402 and peripheral interface 403 may be connected by bus or signal lines. Each peripheral may be connected to the peripheral interface 403 via a bus, signal line, or circuit board. Specifically, the peripheral device includes: at least one of radio frequency circuitry 404, a display screen 405, a positioning component 406, and a power supply 407.
The peripheral interface 403 may be used to connect at least one peripheral related to I/O (Input/Output) to the processor 401 and the memory 402. In some embodiments, processor 401, memory 402, and peripheral interface 403 are integrated on the same chip or circuit board; in some other embodiments, any one or two of the processor 401, the memory 402 and the peripheral interface 403 may be implemented on a separate chip or circuit board, which is not limited by this embodiment.
The Radio Frequency circuit 404 is used for receiving and transmitting RF (Radio Frequency) signals, also called electromagnetic signals. The radio frequency circuitry 404 communicates with communication networks and other communication devices via electromagnetic signals. The rf circuit 404 converts an electrical signal into an electromagnetic signal to transmit, or converts a received electromagnetic signal into an electrical signal. Optionally, the radio frequency circuit 404 includes: an antenna system, an RF transceiver, one or more amplifiers, a tuner, an oscillator, a digital signal processor, a codec chipset, a subscriber identity module card, and so forth. The radio frequency circuitry 404 may communicate with other terminals via at least one wireless communication protocol. The wireless communication protocols include, but are not limited to: the world wide web, metropolitan area networks, intranets, generations of mobile communication networks (2G, 3G, 4G, and 5G), Wireless local area networks, and/or WiFi (Wireless Fidelity) networks. In some embodiments, the rf circuit 404 may further include NFC (Near Field Communication) related circuits, which are not limited in this application.
The Display 405 may be used to Display a UI (User Interface) that may include graphics, text, icons, video, and any combination thereof, when the Display 405 is a Display, the Display 405 may also have the ability to capture touch signals on or over a surface of the Display 405. the touch signals may be input to the processor 401 for processing as control signals, at which time the Display 405 may also be used to provide virtual buttons and/or a virtual keyboard, also referred to as soft buttons and/or a soft keyboard. in some embodiments, the Display 405 may be one, providing a front panel of the terminal 400, in other embodiments, the Display 405 may be at least two, each disposed on a different surface of the terminal 400 or in a folded design, in still other embodiments, the Display 405 may be a flexible Display disposed on a curved surface or on a folded surface of the terminal 400. even, the Display 405 may be disposed in a non-rectangular irregular pattern, the Display 405 may be fabricated from L CD (L idCry Display, Display), Emotig L, Organic light Emitting Diode, or the like.
The positioning component 406 is used to locate the current geographic location of the terminal 400 to implement navigation or L BS (L geographic based Service). the positioning component 406 can be a positioning component based on the united states GPS (global positioning System), the chinese beidou System, or the russian galileo System.
The power supply 407 is used to supply power to the various components in the terminal 400. The power source 407 may be alternating current, direct current, disposable or rechargeable. When the power source 407 includes a rechargeable battery, the rechargeable battery may be a wired rechargeable battery or a wireless rechargeable battery. The wired rechargeable battery is a battery charged through a wired line, and the wireless rechargeable battery is a battery charged through a wireless coil. The rechargeable battery may also be used to support fast charge technology.
Those skilled in the art will appreciate that the configuration shown in fig. 4 is not intended to be limiting of terminal 400 and may include more or fewer components than those shown, or some components may be combined, or a different arrangement of components may be used.
In the above embodiments, there is also provided a non-transitory computer-readable storage medium comprising instructions for storing at least one instruction for execution by a processor to implement the method provided by the above embodiments shown in fig. 1 or fig. 2.
Embodiments of the present application also provide a computer program product containing instructions, which when run on a computer, cause the computer to perform the method provided in the embodiments shown in fig. 1 or fig. 2.
It will be understood by those skilled in the art that all or part of the steps for implementing the above embodiments may be implemented by hardware, or may be implemented by a program instructing relevant hardware, where the program may be stored in a computer-readable storage medium, and the above-mentioned storage medium may be a read-only memory, a magnetic disk or an optical disk, etc.
The above description is only exemplary of the present application and should not be taken as limiting the present application, as any modification, equivalent replacement, or improvement made within the spirit and principle of the present application should be included in the protection scope of the present application.

Claims (11)

1. A method for determining a shale gas well fracturing modification scheme is characterized by comprising the following steps:
the method comprises the steps of obtaining the formation temperature, the gas deviation coefficient, the initial formation pressure, the production formation pressure and the accumulated gas yield of each gas well in a plurality of gas wells, and the landform volume, the landform pressure, the porosity, the water saturation, the density and the adsorption methane density of a shale reservoir layer corresponding to each gas well, wherein the plurality of gas wells are produced by adopting different fracturing modification schemes respectively, and the production formation pressure and the accumulated gas yield refer to the production formation pressure and the accumulated gas yield of the gas wells after a period of time;
determining the initial gas content and the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient, the initial formation pressure and the production formation pressure of each gas well, and the Lanzhou volume, Lanzhou pressure, porosity, water saturation, density and adsorption methane density of a shale reservoir corresponding to each gas well;
determining the fracturing modification volume of each gas well based on the initial gas content, the residual gas content, the accumulated gas yield and the corresponding density of the shale reservoir;
displaying the fracturing modification scheme and the fracturing modification volume of each gas well in the plurality of gas wells;
and selecting one gas well with the largest fracturing modification volume from the plurality of gas wells, and determining the fracturing modification scheme of the selected gas well as the fracturing modification scheme of the shale gas well.
2. The method of claim 1, wherein determining the initial gas content and the residual gas content of each gas well based on the formation temperature, the gas deviation factor, the initial formation pressure and the production formation pressure of each gas well, and the landed volume, the landed pressure, the porosity, the water saturation, the density and the adsorbed methane density of the shale reservoir corresponding to each gas well comprises:
determining the initial gas content of each gas well based on the formation temperature, the gas deviation coefficient and the initial formation pressure of each gas well, and the Lanzhou volume, Lanzhou pressure, porosity, water saturation, density and adsorption methane density of the shale reservoir corresponding to each gas well;
and determining the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient and the production formation pressure of each gas well, and the Lange volume, Lange pressure, porosity, water saturation, density and adsorbed methane density of the shale reservoir corresponding to each gas well.
3. The method of claim 2, wherein determining the initial gas content of each gas well based on the formation temperature, the gas deviation factor, and the initial formation pressure of each gas well, and the landed volume, the landed pressure, the porosity, the water saturation, the density, and the adsorbed methane density of the shale reservoir corresponding to each gas well comprises:
determining the initial adsorption gas volume of each gas well according to a first relational expression based on the initial formation pressure of each gas well and the Lanzhou volume and Lanzhou pressure of the shale reservoir corresponding to each gas well;
wherein the first relation is:
Figure FDA0002406312820000021
wherein, VLIs a blue volume, PLIs a blue pressure, P is a pressure, VadsFor adsorbing gas, when P is the initial formation pressure, VadsThe initial adsorption gas amount;
determining the initial free gas quantity of each gas well according to a second relational expression based on the initial formation pressure, the initial adsorbed gas quantity, the formation temperature and the gas deviation coefficient of each gas well as the porosity, the water saturation, the density and the adsorbed methane density of the shale reservoir corresponding to each gas well;
wherein the second relation is:
Figure FDA0002406312820000022
wherein the content of the first and second substances,
Figure FDA0002406312820000023
porosity of shale reservoir, SWWater saturation of shale reservoir, VadsTo adsorb the gas quantity, ρrockDensity of shale reservoir, MCH4Amount of substance which is methane, VCH4Molar volume of methane in standard conditions, padsAdsorbed methane density, T, for shale reservoirs0Is the formation temperature, Z0Is a gas deviation coefficient, PSCFor pressure under standard conditions, TSCIs the temperature at standard conditions, P is the pressure, VfreeIs the amount of free gas, V is when P is the initial formation pressureadsIs the initial adsorbed gas quantity, VfreeThe initial free gas amount;
and determining the sum of the initial free gas quantity and the initial adsorbed gas quantity of each gas well as the initial gas content of each gas well.
4. The method of claim 1, wherein determining the fracture modification volume for each gas well based on the initial gas content, the residual gas content, the cumulative gas production, and the density of the corresponding shale reservoir for each gas well comprises:
determining the difference value between the initial gas content and the residual gas content of each gas well to obtain the gas content difference value of each gas well;
and determining the fracturing modification volume of each gas well based on the gas content difference value of each gas well, the accumulated gas production and the density of the corresponding shale reservoir.
5. The method of claim 4, wherein determining the fracture modification volume for each gas well based on the gas content difference for each gas well, the cumulative gas production, and the density of the corresponding shale reservoir comprises:
determining the fracturing modification volume of each gas well according to the following third relation formula based on the gas content difference value, the accumulated gas production rate and the density of the corresponding shale reservoir;
wherein the third relation is:
Figure FDA0002406312820000031
wherein SRV is the fracture reconstruction volume, Q1For cumulative gas production, △ V is the difference in gas content, ρrockIs the density of the shale reservoir.
6. An apparatus for determining a shale gas well fracturing modification plan, the apparatus comprising:
an acquisition module: the method comprises the steps of obtaining the formation temperature, the gas deviation coefficient, the initial formation pressure, the production formation pressure and the accumulated gas yield of each gas well in a plurality of gas wells, and the landform volume, the landform pressure, the porosity, the water saturation, the density and the adsorption methane density of a shale reservoir layer corresponding to each gas well, wherein the plurality of gas wells are produced by adopting different fracturing modification schemes respectively, and the production formation pressure and the accumulated gas yield refer to the production formation pressure and the accumulated gas yield of the gas wells after a period of time;
a first determination module: determining the initial gas content and the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient, the initial formation pressure and the production formation pressure of each gas well, and the Lanzhou volume, Lanzhou pressure, porosity, water saturation, density and adsorption methane density of a shale reservoir corresponding to each gas well;
a second determination module: determining the fracturing modification volume of each gas well based on the initial gas content, the residual gas content, the accumulated gas yield and the corresponding density of the shale reservoir;
a display module: displaying the fracturing modification scheme and the fracturing modification volume of each gas well in the plurality of gas wells;
a third determination module: and selecting one gas well with the largest fracturing modification volume from the plurality of gas wells, and determining the fracturing modification scheme of the selected gas well as the fracturing modification scheme of the shale gas well.
7. The apparatus of claim 6, wherein the first determining module comprises:
a first determination unit: determining the initial gas content of each gas well based on the formation temperature, the gas deviation coefficient and the initial formation pressure of each gas well, and the Lanzhou volume, Lanzhou pressure, porosity, water saturation, density and adsorption methane density of the shale reservoir corresponding to each gas well;
a second determination unit: and determining the residual gas content of each gas well based on the formation temperature, the gas deviation coefficient and the production formation pressure of each gas well, and the Lange volume, Lange pressure, porosity, water saturation, density and adsorbed methane density of the shale reservoir corresponding to each gas well.
8. The apparatus of claim 7, wherein the first determining unit comprises:
a first determining subunit: determining the initial adsorption gas volume of each gas well according to a first relational expression based on the initial formation pressure of each gas well and the Lanzhou volume and Lanzhou pressure of the shale reservoir corresponding to each gas well;
wherein the first relation is:
Figure FDA0002406312820000041
wherein, VLIs a blue volume, PLIs a blue pressure, P is a pressure, VadsFor adsorbing gas, when P is the initial formation pressure, VadsThe initial adsorption gas amount;
a second determination subunit: determining the initial free gas quantity of each gas well according to a second relational expression based on the initial formation pressure, the initial adsorbed gas quantity, the formation temperature and the gas deviation coefficient of each gas well as the porosity, the water saturation, the density and the adsorbed methane density of the shale reservoir corresponding to each gas well;
wherein the second relation is:
Figure FDA0002406312820000042
wherein the content of the first and second substances,
Figure FDA0002406312820000043
porosity of shale reservoir, SWWater saturation of shale reservoir, VadsTo adsorb the gas quantity, ρrockDensity of shale reservoir, MCH4Amount of substance which is methane, VCH4Molar volume of methane in standard conditions, padsAdsorbed methane density, T, for shale reservoirs0Is the formation temperature, Z0Is a gas deviation coefficient, PSCFor pressure under standard conditions, TSCIs the temperature at standard conditions, P is the pressure, VfreeIs the amount of free gas, V is when P is the initial formation pressureadsIs the initial adsorbed gas quantity, VfreeThe initial free gas amount;
a third determining subunit: and determining the sum of the initial free gas quantity and the initial adsorbed gas quantity of each gas well as the initial gas content of each gas well.
9. The apparatus of claim 6, wherein the second determining module comprises:
a third determination unit: determining the difference value between the initial gas content and the residual gas content of each gas well to obtain the gas content difference value of each gas well;
a fourth determination unit: and determining the fracturing modification volume of each gas well based on the gas content difference value of each gas well, the accumulated gas production and the density of the corresponding shale reservoir.
10. The apparatus of claim 9, wherein the fourth determination unit comprises:
a fourth determination subunit: determining the fracturing modification volume of each gas well according to the following third relation formula based on the gas content difference value, the accumulated gas production rate and the density of the corresponding shale reservoir;
wherein the third relation is:
Figure FDA0002406312820000051
wherein SRV is the fracture reconstruction volume, Q1For cumulative gas production, △ V is the difference in gas content, ρrockIs the density of the shale reservoir.
11. A computer-readable storage medium, in which a computer program is stored which, when being executed by a processor, carries out the method of any one of claims 1 to 5.
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