CN117233065A - Shale relative permeability determination method and device and electronic equipment - Google Patents
Shale relative permeability determination method and device and electronic equipment Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 74
- 230000035699 permeability Effects 0.000 title claims abstract description 72
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Chemical compound O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 119
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims abstract description 48
- 239000007789 gas Substances 0.000 claims abstract description 36
- 238000001179 sorption measurement Methods 0.000 claims abstract description 30
- 238000002474 experimental method Methods 0.000 claims abstract description 28
- 238000002336 sorption--desorption measurement Methods 0.000 claims abstract description 26
- 229910052757 nitrogen Inorganic materials 0.000 claims abstract description 24
- 239000012071 phase Substances 0.000 claims abstract description 22
- 239000007791 liquid phase Substances 0.000 claims abstract description 19
- 239000012159 carrier gas Substances 0.000 claims abstract description 8
- 238000012545 processing Methods 0.000 claims description 13
- 229920006395 saturated elastomer Polymers 0.000 claims description 7
- 238000012544 monitoring process Methods 0.000 claims description 2
- 238000011161 development Methods 0.000 abstract description 6
- 238000010586 diagram Methods 0.000 description 15
- 238000003860 storage Methods 0.000 description 14
- 238000004590 computer program Methods 0.000 description 11
- 230000008569 process Effects 0.000 description 10
- 239000012530 fluid Substances 0.000 description 8
- 239000011148 porous material Substances 0.000 description 8
- 230000006870 function Effects 0.000 description 7
- 239000007788 liquid Substances 0.000 description 6
- 230000008859 change Effects 0.000 description 4
- 239000000843 powder Substances 0.000 description 4
- 230000003287 optical effect Effects 0.000 description 3
- 239000011435 rock Substances 0.000 description 3
- 239000012808 vapor phase Substances 0.000 description 3
- 230000005540 biological transmission Effects 0.000 description 2
- 238000001035 drying Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000002093 peripheral effect Effects 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 239000003079 shale oil Substances 0.000 description 2
- 238000009736 wetting Methods 0.000 description 2
- 238000003491 array Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 238000000227 grinding Methods 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 230000009878 intermolecular interaction Effects 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000011022 operating instruction Methods 0.000 description 1
- 238000005325 percolation Methods 0.000 description 1
- 230000003068 static effect Effects 0.000 description 1
- 230000005514 two-phase flow Effects 0.000 description 1
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A10/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE at coastal zones; at river basins
- Y02A10/40—Controlling or monitoring, e.g. of flood or hurricane; Forecasting, e.g. risk assessment or mapping
Abstract
The application relates to the technical field of oil and gas development, and discloses a method and a device for determining shale relative permeability and electronic equipment; the method comprises the following steps: obtaining a shale sample; dynamic steam adsorption-desorption data of shale samples are obtained based on dynamic steam adsorption experiments; the dynamic steam adsorption experiment is carried out in a relative humidity balance chamber where nitrogen and steam are mixed, and the relative humidity environment with different degrees is realized by changing the proportion of the nitrogen and the steam; dynamic water vapor adsorption experiments utilized a nitrogen stream as a carrier gas to bring water vapor into contact with the shale sample; based on the dynamic water vapor adsorption-desorption data, the relative permeability of the liquid phase and the relative permeability of the gas phase are determined. The method provided by the application has the advantages of less time consumption, simple operation and high result accuracy.
Description
Technical Field
The disclosure relates to the technical field of oil and gas development, in particular to a method and a device for determining shale relative permeability and electronic equipment.
Background
In recent years, shale oil gas gradually replaces conventional oil gas resources, and becomes strategic resources for guaranteeing energy safety in China, and development of unconventional oil gas is a focus of attention of global scientists.
Compared with the conventional oil and gas reservoir, the shale reservoir has complex and changeable pore space, extremely low permeability and porosity, nano pores are mainly arranged at pore throats, and the rock heterogeneity is strong, and the heterogeneity leads to very complex seepage characteristics in the shale reservoir, so that the research on the mobility of shale pore multiphase fluid has important significance for unconventional oil and gas development.
The percolation characteristics of multiphase flow in shale are typically expressed in terms of relative permeability. The existing method for measuring the relative permeability of the gas phase and the liquid phase mainly comprises a steady state method and an unsteady state method, but the treatment process of the two methods is time-consuming and complex, and the measurement result is also uncertain.
Disclosure of Invention
In view of the above, the embodiments of the present application provide a method, an apparatus, and an electronic device for determining the relative permeability of shale, which aim to solve the above problems or at least partially solve the above problems.
In a first aspect, an embodiment of the present application provides a method for determining a relative permeability of shale, the method comprising: obtaining a shale sample; dynamic steam adsorption-desorption data of the shale sample are obtained based on a dynamic steam adsorption experiment; the dynamic steam adsorption experiment is carried out in a relative humidity balance chamber with mixed nitrogen and steam, and different degrees of relative humidity environments are realized by changing the proportion of the nitrogen and the steam; the dynamic water vapor adsorption experiment utilizes a nitrogen flow as a carrier gas to enable water vapor to contact the shale sample; calculating the water saturation and capillary pressure of the shale sample based on the dynamic water vapor adsorption-desorption data; determining a capillary pressure curve characteristic value based on the capillary pressure; determining fitting parameters based on the capillary pressure, water saturation and capillary pressure curve characteristic values; based on the water saturation and the fitting parameters, a relative permeability of the liquid phase and a relative permeability of the gas phase are determined.
In a second aspect, an embodiment of the present application further provides a device for determining a relative permeability of shale, where the device includes: the acquisition module is used for acquiring shale samples; the processing module is used for obtaining dynamic steam adsorption-desorption data of the shale sample based on a dynamic steam adsorption experiment; the dynamic steam adsorption experiment is carried out in a relative humidity balance chamber with mixed nitrogen and steam, and different degrees of relative humidity environments are realized by changing the proportion of the nitrogen and the steam; the dynamic water vapor adsorption experiment utilizes a nitrogen flow as a carrier gas to enable water vapor to contact the shale sample; calculating the water saturation and capillary pressure of the shale sample based on the dynamic water vapor adsorption-desorption data; determining a capillary pressure curve characteristic value based on the capillary pressure; determining fitting parameters based on the capillary pressure, water saturation and capillary pressure curve characteristic values; based on the water saturation and the fitting parameters, a relative permeability of the liquid phase and a relative permeability of the gas phase are determined.
In a third aspect, an embodiment of the present application further provides an electronic device, including: a processor; and a memory arranged to store computer executable instructions that, when executed, cause the processor to perform the steps of the method of determining shale relative permeability as described in the first aspect above.
The above at least one technical scheme adopted by the embodiment of the application can achieve the following beneficial effects:
according to the method for determining the shale relative permeability, a dynamic water vapor adsorption experiment is carried out on a shale sample in a relative humidity balance chamber with mixed nitrogen and water vapor, nitrogen flow is used as carrier gas, water vapor is carried to contact the shale sample, balance under a certain humidity can be achieved quickly, further, the water vapor adsorption quantity under different humidity can be accurately and sensitively determined, and finally, the gas-liquid two-phase relative permeability is calculated based on water vapor adsorption-desorption data.
Drawings
The accompanying drawings, which are included to provide a further understanding of the application and are incorporated in and constitute a part of this specification, illustrate embodiments of the application and together with the description serve to explain the application and do not constitute a limitation on the application. In the drawings:
FIG. 1 shows a flow diagram of a method for determining the relative permeability of shale provided by an embodiment of the application;
FIG. 2 shows an experimental architecture diagram of a dynamic vapor adsorption experiment provided by an embodiment of the present application;
FIG. 3 is a schematic diagram of a water vapor adsorption-desorption curve provided by an embodiment of the present application;
FIG. 4 is a schematic diagram of a capillary pressure curve provided by an embodiment of the present application;
FIG. 5 is a schematic diagram of a capillary pressure fitting curve provided by an embodiment of the present application;
FIG. 6 is a schematic diagram of a liquid phase versus permeability curve and a vapor phase versus permeability curve provided by an embodiment of the present application;
FIG. 7 shows a block diagram of a shale relative permeability determination apparatus provided by an embodiment of the present application;
fig. 8 shows a schematic structural diagram of an electronic device according to an embodiment of the present application.
Detailed Description
In order to make the objects, technical solutions and advantages of the present application more apparent, the technical solutions of the present application will be clearly and completely described below with reference to specific embodiments of the present application and corresponding drawings. It will be apparent that the described embodiments are only some, but not all, embodiments of the application. All other embodiments, which can be made by those skilled in the art based on the embodiments of the application without making any inventive effort, are intended to be within the scope of the application.
It should be noted that the terms "first," "second," and the like in the description and the claims of the present application and the above figures are used for distinguishing between similar objects and not necessarily for describing a particular sequential or chronological order. It is to be understood that such use is interchangeable under appropriate circumstances such that the embodiments of the application described herein are capable of operation in sequences other than those illustrated or otherwise described herein. Furthermore, the terms "include" and variations thereof are to be interpreted as open-ended terms that mean "include, but are not limited to.
Before describing embodiments of the present application in detail, the following technical terms will be described.
Relative permeability: characterizing the flow characteristics of multiphase fluid is an important fundamental data for oil and gas reservoir resource exploitation.
As described in the background art, in recent years, shale oil gas gradually replaces conventional oil gas resources, and becomes strategic resources for guaranteeing energy safety in China, and development of unconventional oil gas is a focus of attention of global scientists.
Compared with the conventional oil and gas reservoir, the shale reservoir has complex and changeable pore space, extremely low permeability and porosity, nano pores are mainly arranged at pore throats, and the rock heterogeneity is strong, and the heterogeneity leads to very complex seepage characteristics in the shale reservoir, so that the research on the mobility of shale pore multiphase fluid has important significance for unconventional oil and gas development.
The current methods for gas-liquid two-phase relative permeability mainly comprise a steady state method and an unsteady state method. The steady state method refers to directly finding the relative permeability using darcy's law each time the reservoir fluid saturation reaches an equilibrium state. But this method is time consuming to determine and does not represent a true fluid flow law in the reservoir.
The unsteady state method is based on water flooding theory, and is characterized in that saturation is a function of time and distance in the water flooding process, the flow of each fluid and the change of pressure difference at two ends of a rock sample along with time under constant pressure difference or constant speed are measured in the displacement process, the relative permeability of gas-liquid phase is calculated by using the unsteady state relative permeability release method, and a relation curve of the relative permeability and the water saturation is drawn. The unsteady state method is shorter than the steady state method in use, but the calculated result has a larger difference from the actual value due to fewer factors considered by the method. And the unsteady state method is very complex in data processing and various in methods, and the uncertainty of the result is caused.
Based on the method, the method for determining the shale relative permeability is provided, dynamic vapor adsorption experiments are carried out on shale samples, the vapor adsorption quantity under different humidity can be accurately and sensitively determined based on thermodynamic equilibrium theory, and then the gas-liquid two-phase relative permeability is calculated based on vapor adsorption-desorption data. The present application will be described in detail with reference to specific examples.
Fig. 1 shows a flow chart of a method for determining the relative permeability of shale according to an embodiment of the present application, and as can be seen from fig. 1, the method may include steps S101 to S105:
step S101: a shale sample is obtained.
In some embodiments, the shale sample is shale powder or shale cake, and the shape and weight of the shale sample are not limited in the embodiment of the application.
In some embodiments, the shale sample is subjected to a drying process.
Optionally, the drying process comprises the following steps: the shale samples were placed in a dynamic water vapor adsorber and dried in situ for 10 hours under dry conditions of 378.15K.
In some embodiments, the shale sample is shale powder, the shale powder being derived from grinding the shale sample. Optionally, the shale sample is ground to shale powder having a weight of 50 milligrams and a diameter of 200-400 microns.
Step S102: dynamic steam adsorption-desorption data of shale samples are obtained based on dynamic steam adsorption experiments.
In some embodiments, a DVS intrnsic dynamic water adsorber is selected for dynamic water vapor adsorption experiments.
In some embodiments, the dynamic water vapor adsorption experiments are performed in a relative humidity equilibrium chamber where nitrogen and water vapor are mixed, at a preset temperature. Alternatively, a phaseThe flow rate in the humidity balance chamber is 200cm 3 And/min. Optionally, the preset temperature is 308.15K.
As shown in fig. 2, the present application provides a scene graph for performing a water vapor adsorption experiment.
The nitrogen cylinder is connected with the humidity balance chamber to obtain mixed gas of nitrogen and water vapor, a relative humidity environment of 0% -98% in the humidity balance chamber is realized by changing the mixed gas, a high-resolution microbalance is placed in the humidity balance chamber, and a shale sample is placed on the high-resolution microbalance to record the mass change of the shale sample in real time. When the steam adsorption experiment is carried out, the nitrogen flow is used as carrier gas to carry steam into the sample chamber, and the steam comprehensively contacts the shale sample until the steam adsorption-desorption is balanced. In the experimental process, the high-resolution microbalance monitors the mass of a sample in real time, and rapidly records the mass change after each adsorption-desorption balance under a certain humidity.
In some embodiments, the electronics plot a dynamic water vapor adsorption-desorption curve based on the adsorption-desorption data after the end of the experiment, with an exemplary water vapor adsorption-desorption curve being shown in fig. 3.
In some embodiments, the dynamic water vapor adsorption-desorption data includes at least one of: real-time quality of shale samples, vapor pressure of water in porous media, density of capillary water and adsorbed water, relative humidity, etc.
Step S103: based on the dynamic water vapor adsorption-desorption data, the water saturation and capillary pressure of the shale sample are calculated.
In some embodiments, the water saturation of the shale sample is determined based on the real-time mass, the dry mass, and the saturated mass of the shale sample.
In one embodiment, the water saturationThe determination is based on the following formula:
wherein,indicating water saturation, < >>Representing the real-time quality of shale samples, +.>Indicating mass of dry shale sample, +.>Representing the mass of a saturated shale sample.
In some embodiments, the capillary pressure is determined based on the density of capillary water and adsorbed water, the universal gas constant, the absolute temperature, the molar mass of water, and the relative humidity.
In particular, there is a local thermodynamic equilibrium between liquid water and water vapor during moisture transport. In one-dimensional linear space, the solution phase water and its vapor phase reach thermodynamic equilibrium to satisfy the Kraperon (Clapeyon) equation:
wherein,is the pressure of liquid water, is defined as>Represents the vapor pressure of water in the porous medium, < >>For the density of capillary water and adsorbed water, +.>Is the density of the water vapor.
Considering water vapor and dry air as ideal gases, neglecting intermolecular interactions, integrating the Clapeyon equation to obtain the kelvin equation:
wherein,represents capillary pressure +.>Represents the density of capillary water and adsorbed water, +.>Representing the general gas constant, +.>Indicating absolute temperature, +.>Represents the molar mass of water, < >>Represents the vapor pressure of water in the porous medium, < >>Represents the saturated vapor pressure of pure free water, +.>Indicating relative humidity.
In some embodiments, the capillary pressure curve is drawn based on capillary pressure and water saturation.
Illustratively, the capillary pressure curve is shown in FIG. 4.
Step S104: based on the capillary pressure, a capillary pressure curve characteristic value is determined.
Step S105: fitting parameters are determined based on capillary pressure, water saturation, and capillary pressure curve characteristic values.
In some embodiments, in the porous medium unsaturated two-phase flow, the equilibrium relationship between capillary pressure and water saturation is generally described using the analytical formula set forth by van Genuchten. When the wetting fluid is water and the non-wetting fluid is humid air, the two-parameter van Genuchten equation is expressed as:
wherein,represents a water saturation of +>Capillary pressure at time,/->Indicating water saturation, < >>Characteristic value of capillary pressure curve is indicated, < >>Representing the fitting parameters.
In an exemplary embodiment, a capillary pressure fitting curve is shown in FIG. 5, from which capillary pressure curve characteristic values may be fit=26.40 MPa, fitting parameters +.>=2.13。
Step S106: based on the water saturation and the fitting parameters, a relative permeability of the liquid phase and a relative permeability of the gas phase are determined.
In some embodiments, the relative permeability of the liquid phase is determined based on the following equation:
wherein,represents a water saturation of +>Relative permeability of liquid phase at time, < >>Indicating water saturation, < >>Representing the fitting parameters.
In some embodiments, the relative permeability of the gas phase is determined based on the following equation:
wherein,represents a water saturation of +>Relative permeability of gas phase at time, +.>Indicating the saturation of the water content,representing the fitting parameters.
In some embodiments, the liquid phase relative permeability is plotted based on the liquid phase relative permeability and the gas phase relative permeability is plotted based on the gas phase relative permeability.
In an exemplary embodiment, the liquid phase versus permeability curve and the vapor phase versus permeability curve are shown in FIG. 6.
As can be seen from the method shown in FIG. 1, the method provided by the application can accurately and sensitively determine the water vapor adsorption capacity under different humidity based on the thermodynamic equilibrium theory by carrying out a dynamic water vapor adsorption experiment on the shale sample, and further calculate the gas-liquid two-phase relative permeability based on water vapor adsorption-desorption data.
It should be understood that the sequence number of each step in the foregoing embodiment does not mean that the execution sequence of each process should be determined by the function and the internal logic, and should not limit the implementation process of the embodiment of the present application. Furthermore, the terms "include" and variations thereof are to be interpreted as open-ended terms that include, but are not limited to.
In an embodiment, a device for determining the relative permeability of shale is provided, where the device for determining the relative permeability of shale corresponds to the method for determining the relative permeability of shale in the above embodiment one by one. As shown in fig. 7, the processing apparatus includes: the acquisition module 701 and the processing module 702. The functional modules are described in detail as follows:
an acquisition module 601 for acquiring a shale sample;
the processing module 602 is configured to obtain dynamic vapor adsorption-desorption data of the shale sample based on a dynamic vapor adsorption experiment; the dynamic steam adsorption experiment is carried out in a relative humidity balance chamber with mixed nitrogen and steam, and different degrees of relative humidity environments are realized by changing the proportion of the nitrogen and the steam; the dynamic water vapor adsorption experiment utilizes a nitrogen flow as a carrier gas to enable water vapor to contact the shale sample; calculating the water saturation and capillary pressure of the shale sample based on the dynamic water vapor adsorption-desorption data; determining a capillary pressure curve characteristic value based on the capillary pressure; determining fitting parameters based on the capillary pressure, water saturation and capillary pressure curve characteristic values; based on the water saturation and the fitting parameters, a relative permeability of the liquid phase and a relative permeability of the gas phase are determined.
In some embodiments of the application, the dynamic water vapor adsorption-desorption data includes a real-time mass of the shale sample, the real-time mass of the shale sample being obtained based on high resolution microbalance monitoring.
In some embodiments of the application, the water saturation of the shale sample is determined based on the following formula:
wherein,indicating water saturation, < >>Representing the real-time quality of shale samples, +.>Indicating mass of dry shale sample, +.>Representing the mass of a saturated shale sample.
In some embodiments of the application, the capillary pressure is determined based on the following formula:
wherein,represents capillary pressure +.>Represents the density of capillary water and adsorbed water, +.>Representing the general gas constant, +.>Indicating absolute temperature, +.>Represents the molar mass of water, < >>Represents the vapor pressure of water in the porous medium, < >>Represents the saturated vapor pressure of pure free water, +.>Indicating relative humidity.
In some embodiments of the application, the fitting parameters are determined based on the following formula:
wherein,represents a water saturation of +>Capillary pressure at time,/->Indicating water saturation, < >>Characteristic value of capillary pressure curve is indicated, < >>Representing the fitting parameters.
In some embodiments of the application, the relative permeability of the liquid phase is determined based on the following formula:
wherein,represents a water saturation of +>Relative permeability of liquid phase at time, < >>Indicating water saturation, < >>Representing the fitting parameters.
In some embodiments of the application, the relative permeability of the gas phase is determined based on the following formula:
wherein,represents a water saturation of +>Relative permeability of gas phase at time, +.>Indicating the saturation of the water content,representing the fitting parameters.
It should be noted that, the above-mentioned determination device for shale relative permeability may be one-to-one corresponding to implement the foregoing determination method for shale relative permeability, which is not described herein.
Fig. 8 shows a schematic structural diagram of an electronic device according to an embodiment of the present application. As shown in fig. 8, at the hardware level, the electronic device comprises a processor, optionally together with an internal bus, a network interface, a memory. The Memory may include a Memory, such as a Random-Access Memory (RAM), and may further include a non-volatile Memory (non-volatile Memory), such as at least 1 disk Memory. Of course, the electronic device may also include hardware required for other services.
The processor, network interface, and memory may be interconnected by an internal bus, which may be an ISA (Industry Standard Architecture ) bus, a PCI (Peripheral Component Interconnect, peripheral component interconnect standard) bus, or EISA (Extended Industry Standard Architecture ) bus, among others. The buses may be divided into address buses, data buses, control buses, etc. For ease of illustration, only one bi-directional arrow is shown in FIG. 8, but not only one bus or type of bus.
And the memory is used for storing programs. In particular, the program may include program code including computer-operating instructions. The memory may include memory and non-volatile storage and provide instructions and data to the processor.
The processor reads the corresponding computer program from the nonvolatile memory into the memory and then runs the computer program to form a shale relative permeability determining device on a logic level. And the processor is used for executing the program stored in the memory and particularly used for executing the method.
The processor may be an integrated circuit chip having signal processing capabilities. In implementation, the steps of the above method may be performed by integrated logic circuits of hardware in a processor or by instructions in the form of software. The processor may be a general-purpose processor, including a central processing unit (Central Processing Unit, CPU), a network processor (Network Processor, NP), etc.; but also digital signal processors (Digital Signal Processor, DSP), application specific integrated circuits (Application Specific Integrated Circuit, ASIC), field programmable gate arrays (Field-Programmable Gate Array, FPGA) or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components. The disclosed methods, steps, and logic blocks in the embodiments of the present application may be implemented or performed. A general purpose processor may be a microprocessor or the processor may be any conventional processor or the like. The steps of the method disclosed in connection with the embodiments of the present application may be embodied directly in the execution of a hardware decoding processor, or in the execution of a combination of hardware and software modules in a decoding processor. The software modules may be located in a random access memory, flash memory, read only memory, programmable read only memory, or electrically erasable programmable memory, registers, etc. as well known in the art. The storage medium is located in a memory, and the processor reads the information in the memory and, in combination with its hardware, performs the steps of the above method.
The electronic device may execute the method for determining the relative permeability of shale provided by the embodiments of the present application, and implement the function of the device for determining the relative permeability of shale in the embodiment shown in fig. 1, which is not described herein.
The embodiments of the present application also provide a computer-readable storage medium storing one or more programs, the one or more programs including instructions, which when executed by an electronic device comprising a plurality of application programs, enable the electronic device to perform the method for determining shale relative permeability provided by the embodiments of the present application.
It will be appreciated by those skilled in the art that embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present application is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems) and computer program products according to embodiments of the application. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
In one typical configuration, a computing device includes one or more processors (CPUs), input/output interfaces, network interfaces, and memory.
The memory may include volatile memory in a computer-readable medium, random Access Memory (RAM) and/or nonvolatile memory, such as Read Only Memory (ROM) or flash memory (flash RAM). Memory is an example of computer-readable media.
Computer readable media, including both non-transitory and non-transitory, removable and non-removable media, may implement information storage by any method or technology. The information may be computer readable instructions, data structures, modules of a program, or other data. Examples of storage media for a computer include, but are not limited to, phase change memory (PRAM), static Random Access Memory (SRAM), dynamic Random Access Memory (DRAM), other types of Random Access Memory (RAM), read Only Memory (ROM), electrically Erasable Programmable Read Only Memory (EEPROM), flash memory or other memory technology, compact disc read only memory (CD-ROM), digital Versatile Discs (DVD) or other optical storage, magnetic cassettes, magnetic tape magnetic disk storage or other magnetic storage devices, or any other non-transmission medium, which can be used to store information that can be accessed by a computing device. Computer-readable media, as defined herein, does not include transitory computer-readable media (transmission media), such as modulated data signals and carrier waves.
It should also be noted that the terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, an element defined by the phrase "comprising one … …" does not exclude the presence of other identical elements in a process, method, article or apparatus that comprises the element.
It will be appreciated by those skilled in the art that embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The foregoing is merely exemplary of the present application and is not intended to limit the present application. Various modifications and variations of the present application will be apparent to those skilled in the art. Any modification, equivalent replacement, improvement, etc. which come within the spirit and principles of the application are to be included in the scope of the claims of the present application.
Claims (9)
1. A method of determining the relative permeability of shale, the method comprising:
obtaining a shale sample;
dynamic steam adsorption-desorption data of the shale sample are obtained based on a dynamic steam adsorption experiment; the dynamic steam adsorption experiment is carried out in a relative humidity balance chamber with mixed nitrogen and steam, and different degrees of relative humidity environments are realized by changing the proportion of the nitrogen and the steam; the dynamic water vapor adsorption experiment utilizes a nitrogen flow as a carrier gas to enable water vapor to contact the shale sample;
calculating the water saturation and capillary pressure of the shale sample based on the dynamic water vapor adsorption-desorption data;
determining a capillary pressure curve characteristic value based on the capillary pressure;
determining fitting parameters based on the capillary pressure, water saturation and capillary pressure curve characteristic values;
based on the water saturation and the fitting parameters, a relative permeability of the liquid phase and a relative permeability of the gas phase are determined.
2. The method of claim 1, wherein the dynamic water vapor adsorption-desorption data comprises a real-time mass of the shale sample, the real-time mass of the shale sample being acquired based on high resolution microbalance monitoring.
3. The method of claim 1, wherein the water saturation of the shale sample is determined based on the following equation:
the method comprises the steps of carrying out a first treatment on the surface of the Wherein (1)>Representing the water saturation, +.>Representing the real-time quality of the shale sample,indicating mass of dry shale sample, +.>Representing the mass of a saturated shale sample.
4. The method of claim 1, wherein the capillary pressure is determined based on the following equation:
the method comprises the steps of carrying out a first treatment on the surface of the Wherein (1)>Represents capillary pressure +.>Represents the density of capillary water and adsorbed water, +.>Representing the general gas constant, +.>Indicating absolute temperature, +.>Represents the molar mass of water, < >>Represents the vapor pressure of water in the porous medium, < >>Represents the saturated vapor pressure of pure free water, +.>Indicating relative humidity.
5. The method of claim 1, wherein the fitting parameters are determined based on the following formula:
the method comprises the steps of carrying out a first treatment on the surface of the Wherein (1)>Represents a water saturation of +>Capillary pressure at time,/->Representing the water saturation, +.>Characteristic values of the capillary pressure curve, +.>Representing the fitting parameters.
6. The method of claim 1, wherein the relative permeability of the liquid phase is determined based on the following equation:
the method comprises the steps of carrying out a first treatment on the surface of the Wherein (1)>Represents a water saturation of +>Relative permeability of liquid phase at time, < >>Representing the water saturation, +.>Representing the fitting parameters.
7. The method of claim 1, wherein the gas phase relative permeability is determined based on the following equation:
the method comprises the steps of carrying out a first treatment on the surface of the Wherein (1)>Represents a water saturation of +>Relative permeability of gas phase at time, +.>Representing the water saturation, +.>Representing the fitting parameters.
8. A device for determining the relative permeability of shale, said device comprising:
the acquisition module is used for acquiring shale samples;
the processing module is used for obtaining dynamic steam adsorption-desorption data of the shale sample based on a dynamic steam adsorption experiment; the dynamic steam adsorption experiment is carried out in a relative humidity balance chamber with mixed nitrogen and steam, and different degrees of relative humidity environments are realized by changing the proportion of the nitrogen and the steam; the dynamic water vapor adsorption experiment utilizes a nitrogen flow as a carrier gas to enable water vapor to contact the shale sample; calculating the water saturation and capillary pressure of the shale sample based on the dynamic water vapor adsorption-desorption data; determining a capillary pressure curve characteristic value based on the capillary pressure; determining fitting parameters based on the capillary pressure, water saturation and capillary pressure curve characteristic values; based on the water saturation and the fitting parameters, a relative permeability of the liquid phase and a relative permeability of the gas phase are determined.
9. An electronic device, comprising:
a processor; and
a memory arranged to store computer executable instructions that, when executed, cause the processor to perform the steps of the method of determining shale relative permeability of any of claims 1-7.
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