CN110532707B - Method and equipment for determining soaking time - Google Patents
Method and equipment for determining soaking time Download PDFInfo
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Abstract
The embodiment of the invention provides a method and equipment for determining soaking time, wherein the method comprises the following steps: obtaining the type information of the fracturing fluid of a target well, and obtaining the gel breaking viscosity of the fracturing fluid according to the type information of the fracturing fluid; acquiring the usage amount of single fracture fracturing fluid according to a fracturing pump injection program of a target well; obtaining the thickness of an invasion area and the permeability of the invasion area according to the logging data of the target well; and determining the soaking time of the target well according to the gel breaking viscosity of the fracturing fluid, the dosage of the single-fracture fracturing fluid, the thickness of the invaded zone and the permeability of the invaded zone. After the soaking time determined by the embodiment of the invention is adopted for soaking, the flowback rate of the propping agent can be effectively reduced, a better flowback effect can be achieved, and the flow conductivity of cracks can be ensured.
Description
Technical Field
The embodiment of the invention relates to the technical field of determination of soaking time, in particular to a method and equipment for determining soaking time.
Background
In the development process of unconventional shale oil and gas resources, as the unconventional oil and gas resource reservoir conditions have the characteristic of low porosity and low permeability, the large-scale horizontal well multi-section multistage fracturing technology is widely applied. And a horizontal well multistage fracturing technology is adopted, a complex fracture network is formed in a reservoir, and the productivity of the horizontal well is improved.
The construction of the unconventional reservoir horizontal well multi-stage fracturing technology is usually the scale of 'ten thousand square water and thousand square sand', wherein 'ten thousand square water' refers to fracturing fluid, and 'thousand square sand' refers to proppant, so that the flowback of the fracturing fluid is a very important link in the fracturing operation. After fracturing, in order to avoid damage and pollution of fracturing fluid to a reservoir stratum, the flowback is better as early as possible, but after fracturing construction is finished, the fluid injected into a seam and a near seam zone is filled with energy, if the fluid is immediately flowback after the fracturing, the pressure difference of the flowback is very large, the flowback flow rate is very large, the flowback fluid easily carries a propping agent into a shaft, the flow conductivity of the fracture is seriously damaged, therefore, after the fracturing, well stewing is required, and when the fracture is closed to a certain degree, well opening and flowback are carried out.
The fracturing sections of the horizontal well are multiple sections, and the horizontal well is sequentially fractured and sealed from the toe end crack to the root end crack, the root end crack is finally completed by fracturing, and the previous cracks are in different closure degrees. Therefore, during the soaking period, the pressure in the root end crack is highest and is minimum compared with the closing degree of other cracks, and the soaking time is determined only according to the closing degree of the root end crack.
However, the existing determination of the soaking time mainly depends on field experience, and for the volume transformation of an unconventional hypotonic reservoir stratum, great blindness and randomness exist in the determination of the soaking time, so that the flow-back effect after soaking is poor.
Disclosure of Invention
The embodiment of the invention provides a method and equipment for determining soaking time, which aim to solve the problem that the determination of the soaking time in the prior art is poor in backflow effect after soaking due to the fact that the determination of the soaking time is blind and random greatly mainly depending on field experience.
In a first aspect, an embodiment of the present invention provides a method for determining a soaking time, including:
obtaining the type information of the fracturing fluid of a target well, and obtaining the gel breaking viscosity of the fracturing fluid according to the type information of the fracturing fluid;
acquiring the usage amount of single fracture fracturing fluid according to a fracturing pump injection program of a target well;
obtaining the thickness of an invasion area and the permeability of the invasion area according to the logging data of the target well;
and determining the soaking time of the target well according to the gel breaking viscosity of the fracturing fluid, the dosage of the single-fracture fracturing fluid, the thickness of the invaded zone and the permeability of the invaded zone.
In one possible design, the determining the soaking time of the target well according to the fracturing fluid gel breaking viscosity, the single fracture fluid dosage invasion zone thickness and the invasion zone permeability comprises the following steps:
leading the gel breaking viscosity of the fracturing fluid, the thickness of an invasion area of the dosage of the single-fracture fracturing fluid and the permeability of the invasion area into an optimal soaking time formula:
in the formula, mubThe fracturing fluid gel breaking viscosity is adopted; q is the dosage of the single-fracture fracturing fluid; l isiIs the thickness of the invaded zone; k is a radical ofiPenetration rate of invaded zone; t is the optimal soaking time;
and obtaining the soaking time of the target well.
In one possible design, the method further includes:
obtaining data of gel breaking viscosity, single-fracture fracturing fluid consumption, invasion area thickness and invasion area permeability of multiple groups of selected fracturing fluids of the oil field;
the data of the gel breaking viscosity of each group of fracturing fluid is regressed for the optimal soaking time, the data of the using amount of each group of single fracture fracturing fluid is regressed for the optimal soaking time, the data of the thickness of each group of invasion areas is regressed for the optimal soaking time, and the data of the permeability of each group of invasion areas is regressed for the optimal soaking time, so that a basic relational expression of the gel breaking viscosity of the fracturing fluid and the optimal soaking time, a basic relational expression of the using amount of the single fracture fracturing fluid and the optimal soaking time, a basic relational expression of the thickness of the invasion areas and the optimal soaking time and a basic relational expression of the permeability of the invasion areas and the optimal soaking time are obtained;
multiplying and multiplying an initial optimal stewing time formula by a basic relational expression of the fracturing fluid gel breaking viscosity and the optimal stewing time, a basic relational expression of the single-slit fracturing fluid consumption and the optimal stewing time, a basic relational expression of the invasion area thickness and the optimal stewing time and a basic relational expression of the invasion area permeability and the optimal stewing time to obtain a function coefficient, and performing regression with the optimal stewing time to obtain a value of the function coefficient;
and leading the value of the function coefficient into an initial optimal soaking time formula to obtain an optimal soaking time formula.
In one possible design, the target well is the last leg of a horizontal well multi-stage fracture.
In a second aspect, an embodiment of the present invention provides a soaking time determining apparatus, including:
the first acquisition module is used for acquiring the fracturing fluid type information of the target well and acquiring the gel breaking viscosity of the fracturing fluid according to the fracturing fluid type information;
the second acquisition module is used for acquiring the usage amount of the single-fracture fracturing fluid according to the fracturing pump injection program of the target well;
the third acquisition module is used for obtaining the thickness of an invasion area and the permeability of the invasion area according to the logging data of the target well;
and the stewing time determining module is used for determining the stewing time of the target well according to the gel breaking viscosity of the fracturing fluid, the dosage of the single-fracture fracturing fluid, the thickness of an invasion area and the permeability of the invasion area.
In one possible design of the system, the system may be,
the soaking time determining module is specifically used for leading the fracturing fluid gel breaking viscosity, the single-crack fracturing fluid dosage invasion area thickness and the invasion area permeability into an optimal soaking time formula:
in the formula, mubThe fracturing fluid gel breaking viscosity is adopted; q is the dosage of the single-fracture fracturing fluid; l isiIs the thickness of the invaded zone; k is a radical ofiPenetration rate of invaded zone; t is the optimal soaking time;
and obtaining the soaking time of the target well.
In one possible design, the apparatus further includes:
the data acquisition module is used for acquiring data of gel breaking viscosity, single-fracture fracturing fluid consumption, invasion area thickness and invasion area permeability of multiple groups of fracturing fluids of the selected oil field;
the regression processing module is used for performing regression on the data of the gel breaking viscosity of each group of fracturing fluid on the optimal soaking time, the data of the using amount of each group of single fracture fracturing fluid on the optimal soaking time, the data of the thickness of each group of invasion areas on the optimal soaking time and the data of the permeability of each group of invasion areas on the optimal soaking time to obtain a basic relational expression of the gel breaking viscosity of the fracturing fluid and the optimal soaking time, a basic relational expression of the using amount of the single fracture fracturing fluid and the optimal soaking time, a basic relational expression of the thickness of the invasion areas and the optimal soaking time and a basic relational expression of the permeability of the invasion areas and the optimal soaking time;
the coefficient determining module is used for multiplying a basic relational expression of the gel breaking viscosity of the fracturing fluid and the optimal soaking time, a basic relational expression of the single-fracture fracturing fluid consumption and the optimal soaking time, a basic relational expression of the thickness of an invasion area and the optimal soaking time and a basic relational expression of the permeability of the invasion area and the optimal soaking time by a function coefficient to obtain an initial optimal soaking time formula, and regressing with the optimal soaking time to obtain a value of the function coefficient;
and the formula determination module is used for leading the value of the function coefficient into an initial optimal soaking time formula to obtain the optimal soaking time formula.
In one possible design, the target well is the last leg of a horizontal well multi-stage fracture.
In a third aspect, an embodiment of the present invention provides a device for determining a soaking time, including: at least one processor and memory;
the memory stores computer-executable instructions;
the at least one processor executing the computer-executable instructions stored by the memory causes the at least one processor to perform the method for determining a soak time as described above in the first aspect and in various possible designs of the first aspect.
In a fourth aspect, embodiments of the present invention provide a computer-readable storage medium, in which computer-executable instructions are stored, and when the computer-executable instructions are executed by a processor, the method for determining the soaking time according to the first aspect and various possible designs of the first aspect is implemented.
According to the method and the device for determining the soaking time, provided by the embodiment of the invention, the fracturing fluid gel breaking viscosity of the fracturing fluid is obtained according to the fracturing fluid type information of a target well by obtaining the fracturing fluid type information of the target well; acquiring the usage amount of single fracture fracturing fluid according to a fracturing pump injection program of a target well; obtaining the thickness of an invasion area and the permeability of the invasion area according to the logging data of the target well; and determining the soaking time of the target well according to the gel breaking viscosity of the fracturing fluid, the dosage of the single-fracture fracturing fluid, the thickness of the invaded zone and the permeability of the invaded zone. After the soaking time determined by the embodiment of the invention is adopted for soaking, the flowback rate of the propping agent can be effectively reduced, a better flowback effect can be achieved, and the flow conductivity of cracks is ensured.
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In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings needed to be used in the description of the embodiments or the prior art will be briefly introduced below, and it is obvious that the drawings in the following description are some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to these drawings without creative efforts.
Fig. 1 is a schematic diagram of an architecture of a system for determining a satisfactory degree of a soaking time determination according to an embodiment of the present invention;
fig. 2 is a first schematic flow chart of a method for determining a soaking time according to an embodiment of the present invention;
fig. 3 is a second schematic flow chart of a method for determining a soaking time according to an embodiment of the present invention;
FIG. 4 is a graph comparing soak times calculated by numerical simulations and an optimal soak time formula according to an embodiment of the present invention for different fracture fluid gel breaking viscosities;
FIG. 5 is a graph comparing soak times calculated by numerical simulations and an optimal soak time formula according to an embodiment of the present disclosure for different single fracture fracturing fluid dosages;
FIG. 6 is a graph comparing soak times calculated from numerical simulations at different invaded zone thicknesses and the optimal soak time formula of the present invention;
figure 7 is a graph comparing soaking times calculated by numerical simulations and the optimal soaking time formula of the present embodiment at different invaded zone permeabilities;
fig. 8 is a schematic structural diagram of the soaking time determination device according to the embodiment of the present invention;
fig. 9 is a schematic diagram of a hardware structure of the device for determining soaking time according to the embodiment of the present invention
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are some, but not all, embodiments of the present invention. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
Fig. 1 is a schematic structural diagram of a system for determining a satisfaction degree of a soaking time according to an embodiment of the present invention. As shown in fig. 1, the system provided by the present embodiment includes a terminal 101 and a server 102. The terminal 101 may be a mobile phone, a tablet, or the like. The present embodiment does not particularly limit the implementation manner of the terminal 101. The server 102 may be one or a cluster of multiple servers.
Fig. 2 is a first flowchart of a method for determining a soaking time according to an embodiment of the present invention, where an execution subject of this embodiment may be a terminal in the embodiment shown in fig. 1, or may also be a server in the embodiment shown in fig. 1, and this embodiment is not limited herein. As shown in fig. 2, the method includes:
s201, obtaining fracturing fluid type information of a target well, and obtaining fracturing fluid gel breaking viscosity according to the fracturing fluid type information.
In this embodiment, the fracturing fluid type information may include information such as the type, density, and viscosity of the fracturing fluid.
Specifically, the gel breaking viscosity of the fracturing fluid can be obtained from the fracturing fluid type information by identifying the characteristic characters. Wherein the characteristic character may be "viscosity".
S202, obtaining the dosage of the single fracture fracturing fluid according to the fracturing pump injection program of the target well.
In this embodiment, the fracturing pumping program of the target well is a program designed in actual construction, and the single fracture fracturing fluid usage amount is obtained from a program file.
S203, obtaining the thickness of the invasion area and the permeability of the invasion area according to the logging data of the target well.
In the present embodiment, the log data of the target well includes, but is not limited to, electrical, sonic, radioactive, and other logs.
Electrical logging may include, among others, ordinary resistivity logging, lateral logging, induction logging, and micro-resistance logging.
Sonic logging may include acoustic amplitude logging and sonic logging.
Emission logs may include gamma-ray logs, neutron logs, density logs, radioisotope logs, and nuclear magnetic resonance logs.
Other logs may include caliper logs, electromagnetic wave logs, formation dip logs, imaging logs, temperature logs, pressure logs, and water hold logs.
And S204, determining the soaking time according to the target well according to the gel breaking viscosity of the fracturing fluid, the dosage of the single-fracture fracturing fluid, the thickness of the invaded zone and the permeability of the invaded zone.
In this embodiment, determining the soak time of the target well according to the fracturing fluid gel breaking viscosity, the single fracture fracturing fluid dosage invasion zone thickness and the invasion zone permeability comprises:
leading the gel breaking viscosity of the fracturing fluid, the thickness of an invasion area of the dosage of the single-fracture fracturing fluid and the permeability of the invasion area into an optimal soaking time formula:
in the formula, mubThe fracturing fluid gel breaking viscosity is adopted; q is the dosage of the single-fracture fracturing fluid; l isiIs the thickness of the invaded zone; k is a radical ofiPenetration rate of invaded zone; and t is the optimal soaking time.
According to the description, the soaking time of the target well is determined according to the gel breaking viscosity of the fracturing fluid, the single-fracture fracturing fluid dosage, the thickness of the invaded zone and the permeability of the invaded zone, the flowback rate of the propping agent can be effectively reduced after soaking, a good flowback effect can be achieved, and the flow conductivity of the fracture is ensured.
Fig. 3 is a schematic flow chart diagram of a method for determining a soaking time according to an embodiment of the present invention, and this embodiment describes in detail how to determine an optimal soaking time formula according to this embodiment on the basis of the embodiment of fig. 2. As shown in fig. 3, the method includes:
s301, obtaining data of gel breaking viscosity, single-fracture fracturing fluid consumption, invasion area thickness and invasion area permeability of multiple groups of fracturing fluids of the selected oil field.
And S302, performing regression on the optimal soaking time by using the data of the gel breaking viscosity of each group of fracturing fluid, performing regression on the optimal soaking time by using the data of the dosage of each group of single fracture fracturing fluid, performing regression on the optimal soaking time by using the data of the thickness of each group of invasion areas and performing regression on the optimal soaking time by using the data of the permeability of each group of invasion areas to obtain a basic relational expression of the gel breaking viscosity of the fracturing fluid and the optimal soaking time, a basic relational expression of the dosage of the single fracture fracturing fluid and the optimal soaking time, a basic relational expression of the thickness of the invasion areas and the optimal soaking time and a basic relational expression of the permeability of the invasion areas and the optimal soaking time.
And S303, multiplying and multiplying the initial optimal shut-in time formula by a function coefficient according to a basic relational expression of the gel breaking viscosity of the fracturing fluid and the optimal shut-in time, a basic relational expression of the single-fracture fracturing fluid dosage and the optimal shut-in time, a basic relational expression of the invasion area thickness and the optimal shut-in time and a basic relational expression of the invasion area permeability and the optimal shut-in time, and regressing with the optimal shut-in time to obtain a value of the function coefficient.
And S304, introducing the value of the function coefficient into an initial optimal soaking time formula to obtain an optimal soaking time formula.
In this embodiment, the selected data of the gel breaking viscosity, the single fracture fracturing fluid dosage, the thickness of the invaded zone and the permeability of the invaded zone of the oil field can be the fracturing well from a certain oil field. Basic parameters thereofThe formation pressure is 34.5Mpa, the average porosity of the formation is 6.1 percent, and the average permeability is 0.16 multiplied by 10-3μm2. The interval of the fracturing sections is 100m, the viscosity of the well fracturing fluid is 10 mPa.s, the half field of the crack is 130m, and the flow conductivity of the crack is 10 mu m2。
The soak times calculated by numerical simulation and using the optimal soak time formula of the embodiment of the present invention are shown in fig. 4 to 8. Therefore, the soaking time calculated by the optimal soaking time formula is close to the result of numerical simulation, and the effect is accurate.
FIG. 4 is a graph comparing the soak times calculated by numerical simulations and the optimal soak time formula of the embodiments of the present invention at different fracture fluid gel breaking viscosities.
FIG. 5 is a graph comparing soak times calculated by numerical simulations and an optimal soak time formula according to embodiments of the present invention for different single fracture fluid dosages.
Figure 6 is a graph comparing the soak times calculated from numerical simulations at different invaded zone thicknesses and the optimal soak time formula of the present invention.
Figure 7 is a graph comparing the soak times calculated from numerical simulations and the optimal soak time formula of the present embodiment at different invaded zone permeabilities.
Fig. 8 is a schematic structural diagram of the soaking time determination device according to the embodiment of the present invention. As shown in fig. 8, the soaking time determining apparatus 80 includes: a first acquisition module 801, a second acquisition module 802, a third acquisition module 803, and a soak time determination module 804.
The first obtaining module 801 is used for obtaining fracturing fluid type information of a target well and obtaining fracturing fluid gel breaking viscosity according to the fracturing fluid type information;
a second obtaining module 802, configured to obtain a single fracture fracturing fluid usage amount according to a fracturing pump injection procedure of a target well;
a third obtaining module 803, configured to obtain an invaded zone thickness and an invaded zone permeability according to logging data of a target well;
and the soaking time determining module 804 is used for determining the soaking time according to the target well according to the fracturing fluid gel breaking viscosity, the single fracture fracturing fluid dosage, the invasion area thickness and the invasion area permeability.
In an embodiment of the present invention, the soaking time determining module 804 is specifically configured to introduce the fracturing fluid gel breaking viscosity, the single fracture fracturing fluid dosage invasion zone thickness and the invasion zone permeability into an optimal soaking time formula:
in the formula, mubThe fracturing fluid gel breaking viscosity is adopted; q is the dosage of the single-fracture fracturing fluid; l isiIs the thickness of the invaded zone; k is a radical ofiPenetration rate of invaded zone; t is the optimal soaking time;
and obtaining the soaking time of the target well.
Referring to fig. 8, in one embodiment of the invention, the apparatus 80 further comprises: a data acquisition module 805, a regression processing module 806, a coefficient determination module 807, and a formula determination module 808.
The data acquisition module 805 is used for acquiring data of gel breaking viscosity, single-fracture fracturing fluid dosage, invasion area thickness and invasion area permeability of multiple groups of fracturing fluids of the selected oil field;
the regression processing module 806 is used for performing regression on the data of the gel breaking viscosity of each group of fracturing fluids on the optimal soaking time, performing regression on the data of the usage amount of each group of single fracture fracturing fluids on the optimal soaking time, performing regression on the data of the thickness of each group of invasion areas on the optimal soaking time, and performing regression on the data of the permeability of each group of invasion areas on the optimal soaking time to obtain a basic relational expression of the gel breaking viscosity of the fracturing fluids and the optimal soaking time, a basic relational expression of the usage amount of the single fracture fracturing fluids and the optimal soaking time, a basic relational expression of the thickness of the invasion areas and the optimal soaking time, and a basic relational expression of the permeability of the invasion areas and the optimal soaking time;
a coefficient determining module 807 for multiplying and multiplying the basic relational expression of the fracturing fluid gel breaking viscosity and the optimal soaking time, the basic relational expression of the single fracture fracturing fluid consumption and the optimal soaking time, the basic relational expression of the invasion area thickness and the optimal soaking time and the basic relational expression of the invasion area permeability and the optimal soaking time by a function coefficient to obtain an initial optimal soaking time formula, and performing regression with the optimal soaking time to obtain a value of the function coefficient;
and a formula determining module 808, configured to introduce the value of the function coefficient into an initial optimal soaking time formula to obtain an optimal soaking time formula.
The device provided in this embodiment may be used to implement the technical solution of the above method embodiment, and the implementation principle and technical effect are similar, which are not described herein again.
Fig. 9 is a schematic diagram of a hardware structure of the soaking time determination device according to the embodiment of the present invention. As shown in fig. 9, the soaking time determination device 90 of the present embodiment includes: a processor 901 and a memory 902; wherein
A memory 902 for storing computer-executable instructions;
the processor 901 is configured to execute the computer-executable instructions stored in the memory to implement the steps performed by the terminal or the server in the above embodiments. Reference may be made in particular to the description relating to the method embodiments described above.
Alternatively, the memory 902 may be separate or integrated with the processor 901.
When the memory 902 is provided separately, the soaking time determination device further includes a bus 903 for connecting the memory 902 and the processor 901.
The embodiment of the invention also provides a computer-readable storage medium, wherein computer-executable instructions are stored in the computer-readable storage medium, and when a processor executes the computer-executable instructions, the method for determining the soaking time is realized.
In the embodiments provided in the present invention, it should be understood that the disclosed apparatus and method may be implemented in other ways. For example, the above-described device embodiments are merely illustrative, and for example, the division of the modules is only one logical division, and other divisions may be realized in practice, for example, a plurality of modules may be combined or integrated into another system, or some features may be omitted, or not executed. In addition, the shown or discussed mutual coupling or direct coupling or communication connection may be an indirect coupling or communication connection through some interfaces, devices or modules, and may be in an electrical, mechanical or other form.
The modules described as separate parts may or may not be physically separate, and parts displayed as modules may or may not be physical units, may be located in one place, or may be distributed on a plurality of network units. Some or all of the modules may be selected according to actual needs to implement the solution of the present embodiment.
In addition, functional modules in the embodiments of the present invention may be integrated into one processing unit, or each module may exist alone physically, or two or more modules are integrated into one unit. The unit formed by the modules can be realized in a hardware form, and can also be realized in a form of hardware and a software functional unit.
The integrated module implemented in the form of a software functional module may be stored in a computer-readable storage medium. The software functional module is stored in a storage medium and includes several instructions for causing a computer device (which may be a personal computer, a server, or a network device) or a processor to execute some steps of the methods described in the embodiments of the present application.
It should be understood that the Processor may be a Central Processing Unit (CPU), other general purpose Processor, a Digital Signal Processor (DSP), an Application Specific Integrated Circuit (ASIC), etc. A general purpose processor may be a microprocessor or the processor may be any conventional processor or the like. The steps of a method disclosed in connection with the present invention may be embodied directly in a hardware processor, or in a combination of the hardware and software modules within the processor.
The memory may comprise a high-speed RAM memory, and may further comprise a non-volatile storage NVM, such as at least one disk memory, and may also be a usb disk, a removable hard disk, a read-only memory, a magnetic or optical disk, etc.
The bus may be an Industry Standard Architecture (ISA) bus, a Peripheral Component Interconnect (PCI) bus, an Extended ISA (Extended Industry Standard Architecture) bus, or the like. The bus may be divided into an address bus, a data bus, a control bus, etc. For ease of illustration, the buses in the figures of the present application are not limited to only one bus or one type of bus.
The storage medium may be implemented by any type or combination of volatile or non-volatile memory devices, such as Static Random Access Memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic memory, flash memory, magnetic or optical disks. A storage media may be any available media that can be accessed by a general purpose or special purpose computer.
An exemplary storage medium is coupled to the processor such the processor can read information from, and write information to, the storage medium. Of course, the storage medium may also be integral to the processor. The processor and the storage medium may reside in an Application Specific Integrated Circuits (ASIC). Of course, the processor and the storage medium may reside as discrete components in an electronic device or host device.
Those of ordinary skill in the art will understand that: all or a portion of the steps of implementing the above-described method embodiments may be performed by hardware associated with program instructions. The program may be stored in a computer-readable storage medium. When executed, the program performs steps comprising the method embodiments described above; and the aforementioned storage medium includes: various media that can store program codes, such as ROM, RAM, magnetic or optical disks.
Finally, it should be noted that: the above embodiments are only used to illustrate the technical solution of the present invention, and not to limit the same; while the invention has been described in detail and with reference to the foregoing embodiments, it will be understood by those skilled in the art that: the technical solutions described in the foregoing embodiments may still be modified, or some or all of the technical features may be equivalently replaced; and the modifications or the substitutions do not make the essence of the corresponding technical solutions depart from the scope of the technical solutions of the embodiments of the present invention.
Claims (8)
1. A method for determining a soaking time, comprising:
obtaining the type information of the fracturing fluid of a target well, and obtaining the gel breaking viscosity of the fracturing fluid according to the type information of the fracturing fluid;
acquiring the usage amount of single fracture fracturing fluid according to a fracturing pump injection program of a target well;
obtaining the thickness of an invasion area and the permeability of the invasion area according to the logging data of the target well;
determining the soaking time of the target well according to the gel breaking viscosity of the fracturing fluid, the dosage of the single-fracture fracturing fluid, the thickness of an invasion area and the permeability of the invasion area;
determining the soaking time of the target well according to the gel breaking viscosity of the fracturing fluid, the dosage of the single-fracture fracturing fluid, the thickness of an invasion area and the permeability of the invasion area, wherein the soaking time comprises the following steps:
and leading the gel breaking viscosity of the fracturing fluid, the dosage of the single-fracture fracturing fluid, the thickness of an invasion area and the permeability of the invasion area into an optimal soaking time formula:
in the formula, mubThe fracturing fluid gel breaking viscosity is adopted; q is the dosage of the single-fracture fracturing fluid; l isiIs the thickness of the invaded zone; k is a radical ofiPenetration rate of invaded zone; t is the optimal soaking time;
and obtaining the soaking time of the target well.
2. The method of claim 1, further comprising:
obtaining data of gel breaking viscosity, single-fracture fracturing fluid consumption, invasion area thickness and invasion area permeability of multiple groups of selected fracturing fluids of the oil field;
the data of the gel breaking viscosity of each group of fracturing fluid is regressed for the optimal soaking time, the data of the using amount of each group of single fracture fracturing fluid is regressed for the optimal soaking time, the data of the thickness of each group of invasion areas is regressed for the optimal soaking time, and the data of the permeability of each group of invasion areas is regressed for the optimal soaking time, so that a basic relational expression of the gel breaking viscosity of the fracturing fluid and the optimal soaking time, a basic relational expression of the using amount of the single fracture fracturing fluid and the optimal soaking time, a basic relational expression of the thickness of the invasion areas and the optimal soaking time and a basic relational expression of the permeability of the invasion areas and the optimal soaking time are obtained;
multiplying and multiplying an initial optimal stewing time formula by a basic relational expression of the fracturing fluid gel breaking viscosity and the optimal stewing time, a basic relational expression of the single-slit fracturing fluid consumption and the optimal stewing time, a basic relational expression of the invasion area thickness and the optimal stewing time and a basic relational expression of the invasion area permeability and the optimal stewing time to obtain a function coefficient, and performing regression with the optimal stewing time to obtain a value of the function coefficient;
and leading the value of the function coefficient into an initial optimal soaking time formula to obtain an optimal soaking time formula.
3. The method of claim 1, wherein the target well is a last leg of a horizontal well multi-stage fracture.
4. A soak time determination device, comprising:
the first acquisition module is used for acquiring the fracturing fluid type information of the target well and acquiring the gel breaking viscosity of the fracturing fluid according to the fracturing fluid type information;
the second acquisition module is used for acquiring the usage amount of the single-fracture fracturing fluid according to the fracturing pump injection program of the target well;
the third acquisition module is used for obtaining the thickness of an invasion area and the permeability of the invasion area according to the logging data of the target well;
the stewing time determining module is used for determining the stewing time of the target well according to the gel breaking viscosity of the fracturing fluid, the single-fracture fracturing fluid using amount, the thickness of an invasion area and the permeability of the invasion area;
the soaking time determining module is specifically used for leading the fracturing fluid gel breaking viscosity, the single-slit fracturing fluid consumption, the invasion area thickness and the invasion area permeability into an optimal soaking time formula:
in the formula, mubThe fracturing fluid gel breaking viscosity is adopted; q is the dosage of the single-fracture fracturing fluid; l isiIs the thickness of the invaded zone; k is a radical ofiPenetration rate of invaded zone; t is the optimal soaking time;
and obtaining the soaking time of the target well.
5. The apparatus of claim 4, further comprising:
the data acquisition module is used for acquiring data of gel breaking viscosity, single-fracture fracturing fluid consumption, invasion area thickness and invasion area permeability of multiple groups of fracturing fluids of the selected oil field;
the regression processing module is used for performing regression on the data of the gel breaking viscosity of each group of fracturing fluid on the optimal soaking time, the data of the using amount of each group of single fracture fracturing fluid on the optimal soaking time, the data of the thickness of each group of invasion areas on the optimal soaking time and the data of the permeability of each group of invasion areas on the optimal soaking time to obtain a basic relational expression of the gel breaking viscosity of the fracturing fluid and the optimal soaking time, a basic relational expression of the using amount of the single fracture fracturing fluid and the optimal soaking time, a basic relational expression of the thickness of the invasion areas and the optimal soaking time and a basic relational expression of the permeability of the invasion areas and the optimal soaking time;
the coefficient determining module is used for multiplying a basic relational expression of the gel breaking viscosity of the fracturing fluid and the optimal soaking time, a basic relational expression of the single-fracture fracturing fluid consumption and the optimal soaking time, a basic relational expression of the thickness of an invasion area and the optimal soaking time and a basic relational expression of the permeability of the invasion area and the optimal soaking time by a function coefficient to obtain an initial optimal soaking time formula, and regressing with the optimal soaking time to obtain a value of the function coefficient;
and the formula determination module is used for leading the value of the function coefficient into an initial optimal soaking time formula to obtain the optimal soaking time formula.
6. The apparatus of claim 4, wherein the target well is a last leg of a horizontal well multi-stage fracture.
7. A soak time determination device, comprising: at least one processor and memory;
the memory stores computer-executable instructions;
the at least one processor executing computer-executable instructions stored by the memory causes the at least one processor to perform the method of determining soak time as recited in any one of claims 1 to 3.
8. A computer readable storage medium having computer executable instructions stored thereon which, when executed by a processor, implement the method of determining soak time as claimed in any one of claims 1 to 3.
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| CN112949901A (en) * | 2021-01-22 | 2021-06-11 | 中国石油天然气股份有限公司 | Shale oil reservoir horizontal well quasi-natural energy development method and system |
| CN115142827A (en) * | 2021-03-29 | 2022-10-04 | 中国石油化工股份有限公司 | Fracturing process determination method, device, equipment and storage medium |
| CN113586023B (en) * | 2021-07-26 | 2022-07-22 | 中国石油大学(北京) | Method and equipment for determining well closing time after shale oil reservoir pressure |
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