CN108035700B - Simulation system and method for sand carrying rule of shaft of marine natural gas hydrate production well - Google Patents
Simulation system and method for sand carrying rule of shaft of marine natural gas hydrate production well Download PDFInfo
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
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- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/0099—Equipment or details not covered by groups E21B15/00 - E21B40/00 specially adapted for drilling for or production of natural hydrate or clathrate gas reservoirs; Drilling through or monitoring of formations containing gas hydrates or clathrates
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/001—Survey of boreholes or wells for underwater installation
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Abstract
The invention discloses a simulation system and a method for a sand-carrying rule of a shaft of an ocean gas hydrate production well, wherein the simulation system comprises a test well subsystem, a water-gas injection subsystem, a separation subsystem and a shaft monitoring subsystem; the test well subsystem comprises a simulation shaft, a simulation casing, a simulation oil pipe, a gas-liquid mixer, an anti-collapse orifice plate, a fluid director, a gas injection pipeline and a water injection pipeline, wherein the simulation casing, the simulation oil pipe, the gas-liquid mixer, the anti-collapse orifice plate, the fluid director, the gas injection pipeline and the water injection pipeline are arranged in the simulation shaft; the water-gas injection subsystem comprises a high-pressure gas cylinder group and a water tank, the water-gas injection subsystem is respectively connected with the separation subsystem and a wellhead blowout preventer, a resistance imager and a capacitance imager are arranged in a shaft, and are matched with temperature and pressure test data and the opening and closing of a test electromagnetic valve, so that quantitative simulation measurement between a sand-carrying rule and a flow pattern of a natural gas hydrate production well is realized, indirect visual research on the sand-carrying rule of the shaft under different gas-water ratio conditions of the natural gas hydrate production well can be carried out in a full-size mode, a basis can be provided for designing a shaft flow guarantee water injection scheme of the sea natural gas hydrate production well, and the requirement of sand production management measures on shaft sand-carrying capacity analysis in the process of producing silty natural gas hydrate is met.
Description
Technical Field
The invention belongs to the technical field of marine natural gas hydrate resource development engineering, and particularly relates to a simulation system and method capable of visually simulating the actual sand-carrying flowing rule of fluid in a shaft for marine natural gas hydrate exploitation.
Background
The natural gas hydrate resource is a clean energy with extremely high energy density, and more than 90 percent of the global deep sea area meets the conditions of generation and occurrence of the natural gas hydrate. In order to occupy the energy control high point, the exploration and development of the marine natural gas hydrate become the hot point of international energy competition at present. More than 90% of sea natural gas hydrates are stored in seabed low-permeability clay or silty clay reservoirs, and the safe and controllable exploitation of the natural gas hydrates in the world first silty clay reservoirs is successfully realized in northern part of south China, 2017, 5 months, 10 days to 7 months, 9 days, so that the leading position of China in the field is established.
However, no matter the first marine natural gas hydrate trial production project in China or the Japanese marine natural gas hydrate trial production project, the sand production problem is faced. The 'sand prevention' idea in the conventional oil and gas industry is abandoned in the first sea area natural gas hydrate trial production process in China, the reservoir stability is taken as the core, the 'sand production management' concept and the basic response measures in the silt natural gas hydrate production process are provided, and certain support is provided for the first sea area natural gas hydrate trial production success in China. The basic idea of sand production management of the marine natural gas hydrate exploitation well is as follows: proper sand control and prevention and drainage combination are mainly used for drainage. The primary purpose of this is to maintain formation stability and production continuity. That is, if the formation sand moves to the well bottom along with the fluid, the sand control design scheme of 'coarse and fine prevention' is adopted, so that the large-particle size formation sand is blocked by the sand control screen or the gravel layer, but the majority of the shale content and small-particle sandy components in the formation are actively dredged to the well bottom, and the formation sand is produced to the well head platform through the design of the shaft sand carrying scheme.
Therefore, in the trial production process of the natural gas hydrate in the sea area, the dynamic analysis of sand carrying of the shaft is very important for preventing the shaft from being buried by sand and maintaining the normal operation of the lifting system. The flowing rule of formation sand from the bottom of a well to the top of a platform under the condition of gas-liquid ratio of a hydrate production well becomes one of key subjects faced in the process of pilot production of natural gas hydrates. How to observe the migration and aggregation rules of the sand and mud in the natural gas hydrate production shaft by a quantitative visualization means is a difficult point for researching the sand carrying rule of the natural gas hydrate production shaft.
In the aspect of simulation of sand carrying production conditions of a shaft of a conventional oil and gas well, a great number of shaft sand carrying rule observation devices adopting organic glass tubes or even sapphire visual windows are proposed by some researchers at present, the experiment devices are different in size, basically comprise a liquid (gas) supply subsystem, a sand supply subsystem, a simulation shaft, a recovery and treatment subsystem and the like, and the core of the experiment devices is a simulation shaft. The application publication number CN105464606A discloses a simulated sand carrying shaft formed by two layers of transparent concentric glass tubes, which can meet the simulation of a sand carrying rule of a drilling and production double-working-condition shaft under a small-scale low-pressure condition, although the visual experimental means of naked eyes provides convenience for visually observing the quality of the sand carrying effect of the shaft, the visual observation is difficult to achieve the precision of quantitatively evaluating the sand carrying condition, and the visual observation also brings the defects that the high-pressure condition of the actual shaft cannot be borne and the sand carrying rule cannot be quantitatively identified; in addition, there are also some well bore sand carrying effect experimental devices specially aiming at specific fluids (such as foam, patent publication No. CN104280315 a) and special well types (such as highly deviated well, patent publication No. CN 202900235U), and the common points are: the simulation experiment can be carried out only in a small scale range, the influence of the actual shaft size effect and the high-pressure environment effect is rarely considered, and the sand-carrying dynamic quantitative analysis of the natural gas hydrate production well under the condition of multi-component multi-phase flow is not involved.
Different from the conventional simulation of pure water-phase sand-carrying flow or pure gas-phase sand-carrying flow, the natural gas hydrate exploitation well is always in a multiphase multi-component high-pressure flow state, and the influence of the gas-liquid ratio and the temperature-pressure condition of the shaft on the flow pattern is very important, so that the shaft sand-carrying process of the natural gas hydrate exploitation well must be clearly known to the shaft flow pattern firstly. Under the condition of multi-component multi-phase flow of a shaft of a natural gas hydrate exploitation well, parameters such as the critical flow rate condition of sand carrying of the shaft, the sand carrying amount and the like are closely related to the flow pattern, so that if an experimental device can be invented, the high-pressure flow process of the natural gas hydrate exploitation well under different gas-water ratio conditions can be simulated, and the migration and sedimentation rules of sand grains in the shaft under the condition of actual shaft scale can be visually evaluated, very favorable data support can be provided for the design of a natural gas hydrate exploitation well lifting scheme and a shaft flow guarantee scheme.
Disclosure of Invention
The technical problem to be solved by the invention is to provide a simulation system and a simulation method capable of indirectly and visually researching the sand carrying rule of a shaft under the conditions of different gas-water ratios of a natural gas hydrate exploitation well in a full size aiming at the urgent need of the exploitation of marine silty natural gas hydrate in China for the fine management of shaft sand production so as to meet the demand of sand production management measures on the analysis of the sand carrying capacity of the shaft in the exploitation process of the silty natural gas hydrate.
The invention is realized by adopting the following technical scheme:
a simulation system for sand carrying rule of a shaft of an ocean gas hydrate production well comprises a test well subsystem, a water-gas injection subsystem, a separation subsystem and a shaft monitoring subsystem:
the test well subsystem comprises a simulation shaft, a simulation casing, a simulation oil pipe, a gas-liquid mixer, an anti-collapse orifice plate, a fluid director, a gas injection pipeline and a water injection pipeline, wherein the simulation casing, the simulation oil pipe, the gas-liquid mixer, the anti-collapse orifice plate, the fluid director, the gas injection pipeline and the water injection pipeline are arranged in the simulation shaft; the simulation shaft is a full-size natural gas hydrate exploitation simulation well, a wellhead of the simulation shaft is provided with a wellhead blowout preventer, and the wellhead blowout preventer is a bridge for connecting the test well subsystem with the water-gas injection subsystem and the separation subsystem; the simulation oil pipe is arranged in the simulation sleeve and is a common oil pipe with actual on-site dimension, an oil sleeve annulus packer is installed at the position of a simulation oil pipe shoe, and the setting realizes the packing of the simulation sleeve and the simulation oil pipe annulus; the gas-liquid mixer is of an annular structure and is arranged at the bottom of the simulated shaft, the upper end of the gas-liquid mixer is provided with a test electromagnetic valve, and the lower end of the gas-liquid mixer is communicated with the fluid director; the simulation sleeve is connected with the gas-liquid mixer, and the outer diameter of the simulation sleeve is equal to the annular inner diameter of the gas-liquid mixer; the anti-collapse orifice plate is a circular metal porous plate, the outer diameter of the anti-collapse orifice plate is the same as the inner diameter of the simulation sleeve, and the anti-collapse orifice plate is arranged at a pipe shoe on the inner wall of the simulation sleeve to prevent the simulation formation sand below from being broken by fluid in the experiment process and prevent the follow-up experiment from being impossible; a space formed by the anti-collapse orifice plate, the fluid director and the gas-liquid mixer annulus is a filling space for simulating formation sand, the space is filled with actual hydrate formation sand, and the simulated formation sand in the area penetrates through the anti-collapse orifice plate under the carrying effect of gas-liquid mixed fluid in the actual operation process and enters a simulated oil pipe; an oil pipe penetrating packer is further mounted at the position of a pipe shoe of the simulation sleeve to seal an annular space between the simulation sleeve and the wall of the simulation shaft, a plurality of through holes are uniformly formed in the circumferential direction of the simulation sleeve, are arranged close to the position of the pipe shoe, are positioned above the anti-collapse hole plate and are positioned below the oil pipe penetrating packer; the gas injection pipeline and the water injection pipeline penetrate through the oil pipe and penetrate through the packer to be connected with the gas-liquid mixer, and one-way valves are respectively arranged at the joints of the gas injection pipeline and the water injection pipeline with the gas-liquid mixer, so that gas and water can not flow backwards due to pressure difference between the gas injection pipeline and the water injection pipeline;
the water-gas injection subsystem is respectively connected with the separation subsystem and the wellhead blowout preventer, the water-gas injection subsystem comprises a high-pressure gas cylinder group and a water tank which are arranged on the ground, the separation subsystem comprises a gas-liquid-solid separator arranged on the ground, the water tank is connected with a water injection pipeline through an injection pump, and the water tank is connected with a liquid path outlet of the gas-liquid-solid separator and is used for injecting water into the simulation shaft and recovering returned circulating water; the high-pressure gas cylinder group is connected with a gas injection pipeline and a gas path outlet of the gas-liquid-solid separator and is used for injecting gas into the simulation shaft and recovering returned gas to realize gas-liquid circulation, a valve F1 is arranged between the high-pressure gas cylinder group and the gas injection pipeline, a valve F2 is arranged between the injection pump and the water injection pipeline, and a valve F3, a valve F4 and a valve F5 are respectively arranged between the gas-liquid-solid separator and the simulation oil pipe as well as between the high-pressure gas cylinder group and the water tank;
the wellbore monitoring subsystem comprises a resistance imager, a capacitance imager, a temperature sensor and a pressure sensor which are oppositely arranged on the inner wall of the simulation oil pipe; the resistance imager is of an annular structure with the inner diameter consistent with that of the simulation oil pipe, and a male buckle and a female buckle which are matched with the simulation oil pipe are respectively arranged at two ends of the resistance imager and are connected to the simulation oil pipe as a connecting piece of the simulation oil pipe; the capacitance imager is of an annular structure with the inner diameter consistent with that of the oil pipe, and a male buckle and a female buckle which can be matched with the simulation oil pipe are respectively arranged at two ends of the capacitance imager and are connected to the simulation oil pipe as a connecting piece of the simulation oil pipe; the resistance imager and the capacitance imager are connected in series on the simulation oil pipe through a connecting coupling, and the temperature sensor and the pressure sensor are respectively arranged at the equal-height parts of the inner wall of the connecting coupling.
Furthermore, the resistance imager is formed by annularly arranging 16 electrodes, and is used for chromatographic imaging measurement by a four-point method, namely any two electrodes are used as current excitation electrodes, voltage values between any two other electrodes are measured, and a resistivity field distribution rule in the whole plane is obtained through repeated measurement.
Furthermore, the capacitance imager is formed by annularly arranging 16 electrodes, one point of an electrode shell is grounded, current is injected from any point, the capacitance between the electrode point and other electrode points is measured, and the capacitance field distribution in the whole plane is obtained through repeated measurement; the capacitance imager requires the continuous phase of the measured medium to be a conductive medium, so the capacitance imager is suitable for measuring the flow condition of a high gas-liquid ratio shaft with the gas phase as the continuous medium.
Furthermore, the fluid director is a circular structure formed by combining an upper porous screen plate and a lower porous screen plate, the aperture of the lower porous screen plate is larger than that of the upper porous screen plate, the outer edge of the fluid director is connected with a gas-liquid mixer, and the pore size structure of the lower porous screen plate and the upper porous screen plate is large, so that fluid flowing out of the gas-liquid mixer can quickly enter the bottom end face of the well, the fluid can flow into the simulated formation along the direction vertical to the upper simulated formation to form uniform inflow, sand of the upper simulated formation is prevented from being washed away, and an independent large pore channel is formed.
Furthermore, a shunting baffle and a turbine stirrer are arranged inside an annular structure of the gas-liquid mixer, injected gas and liquid are sprayed into the gas-liquid mixer by the shunting baffle in a rotating mode, and the turbine stirrer rotates at a high speed under the impact action of water injected into a water injection pipeline, so that the gas and the liquid are fully stirred and mixed.
Further, the high-pressure gas cylinder group also comprises an air bath temperature control device, so that the temperature of the injected gas is controlled according to the bottom temperature of the actual natural gas hydrate production well.
Further, the water tank comprises a water bath temperature control device so as to control the temperature of the injected liquid according to the bottom temperature of the actual natural gas hydrate production well.
Furthermore, the water injection pipeline and the gas injection pipeline are wrapped by a heat insulation layer so as to ensure that the temperature of the water with the set temperature on the ground is kept unchanged in the process of injecting the water into the well bottom, and the purpose of simulating the well bottom temperature of the actual natural gas hydrate exploitation well is achieved.
Furthermore, the shaft monitoring subsystems comprise two groups which are respectively arranged at the upper part of the simulation oil pipe and the lower part of the simulation oil pipe.
The invention also provides a simulation method based on the simulation system of the sand-carrying rule of the shaft of the marine natural gas hydrate production well, which comprises the following steps:
A. combining the gas-liquid ratio condition of an actual hydrate production well and the size of a shaft oil pipe, and installing a simulated in-well device;
(1) Analyzing the possible gas-liquid ratio range in the natural gas hydrate production well by capacity simulation in combination with the actual stratum clay content, and determining the bottom hole temperature in the natural gas hydrate production well to be simulated according to the stratum temperature and the simulation condition of produced fluid;
(2) Circularly controlling the temperature of the high-pressure gas cylinder group and the water tank to ensure that the temperature of gas and liquid on the ground is consistent with the bottom temperature of an actual natural gas hydrate exploitation well, then installing an in-well device, injecting water into the bottom of the well, and circularly controlling the temperature of a bottom structure of the well;
B. injecting the fixed gas-liquid ratio, and circularly collecting until a stable simulated oil pipe flow pattern is formed:
opening a bottom hole testing electromagnetic valve, injecting gas and liquid phases into a well according to the determined gas-liquid ratio condition, avoiding simulated formation sand, circulating for a period of time, and judging continuous phases and discontinuous phases in a simulated oil pipe and the arrangement relation thereof through a capacitance imager and a resistance imager until a flow pattern in the simulated oil pipe stably exists;
C. adjusting a well bottom flow, carrying sand and producing:
(1) Keeping the ground gas and liquid injection unchanged, closing a bottom hole testing electromagnetic valve, enabling a gas-liquid mixture to flow through simulated formation sand and flow into a simulated oil pipe together with the simulated formation sand, and recording temperature, pressure, capacitance imaging results and resistance imaging results at different well depth positions in real time in the process of the step;
(2) In the sand carrying production process, comparing the capacitance imaging result and the resistance imaging result with the capacitance imaging result and the resistance imaging result under the stable flow pattern condition in the step B, analyzing the distribution and carrying rules of the sand and mud in the simulated oil pipe in gas-liquid two phases, and quantitatively identifying the influence of the sand carrying amount on the flow pattern of the simulated oil pipe and the sand carrying and moving rule under different temperature and pressure conditions;
D. and obtaining shaft sand carrying dynamic under different flow pattern conditions, finishing the simulation process, and providing a proposal for guaranteeing sand carrying flow of the simulated oil pipe.
Compared with the prior art, the invention has the advantages and positive effects that:
the simulation shaft depth range meets the natural gas hydrate burial depth range of the sea area in China, indirect visual research on shaft sand-carrying rules of a natural gas hydrate exploitation well under different gas-water ratio conditions can be carried out in a full-scale mode, the bottom hole temperature of an actual natural gas hydrate exploitation well can be simulated, the simulation process is made to be as close to the bottom hole temperature and pressure condition of the actual natural gas hydrate exploitation well as possible, the requirement of sand production management measures on shaft sand-carrying capacity analysis in the silt natural gas hydrate exploitation process is met, and a basis can be provided for designing a shaft flow guarantee water injection scheme of the sea area natural gas hydrate exploitation well;
the resistance imager and the capacitance imager are installed in the high-pressure shaft in a serial connection mode for the first time, the change condition of the flow pattern in the simulated oil pipe is reflected through the real-time imaging of the imagers, and the sand carrying dynamic state of the natural gas hydrate exploitation shaft can be effectively combined with the actual flow pattern; the resistance imager, the capacitance imager, the temperature sensor and the pressure sensor are combined, so that the method can adapt to the mud sand migration and aggregation rule of a hydrate production shaft in the whole gas-liquid ratio range (the gas content is 0% -the gas content is 100%) under the condition of certain temperature and pressure; the resistance imager and the capacitance imager have the characteristics of high testing speed and high data imaging speed, and can achieve the purpose of regulating and controlling the sand-carrying flowing state of a shaft in real time;
through the special design of the well bottom gas-liquid mixer and the matching of the well bottom gas-liquid mixer and the fluid director, the mixed gas-liquid can bypass the simulated formation sand to flow into the oil pipe at the initial injection stage of the experiment to form a stable flow pattern; after the shaft flow pattern is stable, the gas-liquid mixed fluid flows through the pre-buried simulated formation sand by adjusting the switch of the test electromagnetic valve, so that the purpose of carrying sand for production under the condition of stable flow pattern is achieved; and the design of the flow guider and the anti-collapse orifice plate is combined, so that collapse of underground formation sand due to sudden fluctuation of a gas-liquid mixture or a large-pore passage flow channel formed in sediments is prevented, the simulation process of a sand-carrying state of the shaft can be maintained for a long time, and the experimental phenomenon is convenient to observe.
Drawings
Fig. 1 is a schematic structural diagram of a simulation system according to embodiment 1 of the present invention;
FIG. 2 is a schematic diagram showing the principle of electrical resistance tomography test in embodiment 1 of the present invention;
FIG. 3 is a schematic diagram illustrating the principle of the electrical capacitance tomography test in embodiment 1 of the present invention;
FIG. 4 is a schematic structural view of a flow deflector according to embodiment 1 of the present invention;
FIG. 5 is a simulation flow chart of the sand-carrying law of the wellbore of the hydrate production well in embodiment 2 of the present invention;
wherein, 1, a wellhead blowout preventer; 2. simulating a shaft; 3. a capacitance imager 4, a resistance imager; 5. simulating a casing; 6. simulating an oil pipe; 7. an oil jacket annulus packer; 8. the oil pipe passes through the packer; 9. a gas-liquid mixer; 10. an anti-collapse orifice plate; 11. simulating formation sand; 12. a gas injection line; 13. water is injected into the pipeline; 14. a high pressure gas cylinder group; 15. a gas-liquid-solid separator; 16. a water tank; 17. an injection pump; 18. a pressure sensor; 19. a temperature sensor; 20. a fluid director; 20-1, an upper porous screen plate; 20-2, a lower porous screen plate; F1-F5, high-pressure ball valve; f6, testing the electromagnetic valve; t1-t16: resistance tomography test electrodes; r1 to r16: an electrical capacitance tomography test electrode.
Detailed Description
In order to make the above objects, features and advantages of the present invention more clearly understood, the present invention will be further described with reference to the accompanying drawings and examples. It should be noted that the embodiments and features of the embodiments of the present application may be combined with each other without conflict.
Embodiment 1, a simulation system of sand-carrying law of a shaft of a marine natural gas hydrate production well comprises a test well subsystem, a water-gas injection subsystem, a separation subsystem and a shaft monitoring subsystem, and referring to fig. 1, the test well subsystem comprises a simulation shaft 2, a simulation casing 5, a simulation oil pipe 6, a gas-liquid mixer 9, an anti-collapse orifice plate 10, a fluid director 20, a gas injection pipeline 12 and a water injection pipeline 13, wherein the simulation casing 5, the simulation oil pipe 6, the gas-liquid mixer 9, the anti-collapse orifice plate 10, the fluid director 20, the gas injection pipeline 12 and the water injection pipeline 13 are installed in the simulation shaft 2; the simulated shaft 2 has a depth of 200m and an inner diameter of 16 1 / 2 The full-size natural gas hydrate exploitation simulation well comprises a simulation shaft 2, wherein a wellhead blowout preventer 1 is arranged at the wellhead, and the wellhead blowout preventer is a bridge for connecting a test well subsystem with a water-gas injection subsystem and a separation subsystem.
As can be seen from FIG. 1, the simulated oil pipe 3 is arranged in the simulated casing 5, and is a common oil pipe with actual on-site dimensions, an oil casing annulus packer 7 is installed at a pipe shoe of the simulated oil pipe 3, and the setting realizes the annular packing of the simulated casing 5 and the simulated oil pipe 3; the gas-liquid mixer 9 is of an annular structure and is arranged at the bottom of the simulated shaft 2, the upper end of the gas-liquid mixer is provided with a test electromagnetic valve F6, and the lower end of the gas-liquid mixer is communicated with the fluid director 20; the simulation sleeve 5 is connected with a gas-liquid mixer 9, the outer diameter of the simulation sleeve is equal to the annular inner diameter of the gas-liquid mixer 9, and the simulation sleeve can be connected in a screw thread mode and the like; the anti-collapse orifice plate 10 is a circular metal perforated plate, the outer diameter of the anti-collapse orifice plate is the same as the inner diameter of the simulation sleeve 5, and the anti-collapse orifice plate is arranged at a pipe shoe on the inner wall of the simulation sleeve 5 to prevent the simulation stratum sand below from being broken by fluid in the experiment process to prevent the follow-up experiment from being impossible; a space formed by annular spaces of the anti-collapse orifice plate 10, the fluid director 20 and the gas-liquid mixer 10 is a filling space for simulated formation sand, actual hydrate formation sand, namely the simulated formation sand 11 in the figure 1, is filled in the space, and the simulated formation sand 11 in the area penetrates through the anti-collapse orifice plate 10 under the carrying action of gas-liquid mixed fluid in the actual operation process and enters the simulated oil pipe 6; an oil pipe penetrating packer 8 is further installed at the pipe shoe of the simulation casing 5 to seal an annular space between the simulation casing 5 and the wall of the simulation shaft 2, and a plurality of through holes (schematic positions on the left side of the test electromagnetic valve in fig. 1) are uniformly arranged along the circumferential direction of the simulation casing 5, preferably 6 through holes in the embodiment, are arranged at the position close to the pipe shoe, are positioned above the anti-collapse hole plate 10 and are positioned below the oil pipe penetrating packer 8; the gas injection pipeline 12 and the water injection pipeline 13 penetrate through the oil pipe penetrating packer 8 to be connected with the gas-liquid mixer 10, and one-way valves are respectively arranged at the connection positions of the gas injection pipeline 12 and the water injection pipeline 13 with the gas-liquid mixer 9, so that gas and water can not flow backwards due to pressure difference between the two parts in the gas and water injection process.
The water-gas injection subsystem is respectively connected with the separation subsystem and the wellhead blowout preventer, the water-gas injection subsystem comprises a high-pressure gas cylinder group 14 and a water tank 16 which are arranged on the ground, the separation subsystem comprises a gas-liquid-solid separator 15 arranged on the ground, the water tank 16 is connected with a water injection pipeline 13 through an injection pump 17, and the water tank 16 is connected with a liquid path outlet of the gas-liquid-solid separator 15 and is used for injecting water into the simulation shaft 2 and recovering returned circulating water; the high-pressure gas cylinder group 14 is connected with the gas injection pipeline 12 and the gas path outlet of the gas-liquid-solid separator 15 and is used for injecting gas into the simulated shaft and recovering the returned gas to realize gas-liquid circulation, a valve F1 is arranged between the high-pressure gas cylinder group 14 and the gas injection pipeline 12, a valve F2 is arranged between the injection pump 17 and the water injection pipeline 13, a valve F3, a valve F4 and a valve F5 are respectively arranged between the gas-liquid-solid separator 15 and the simulated oil pipe 6, between the high-pressure gas cylinder group 14 and the water tank 16, and the valves F1-F5 are all high-pressure ball valves,
the wellbore monitoring subsystems are preferably two groups, are respectively arranged at the upper part of the simulation oil pipe 6 and the lower part of the simulation oil pipe 6, and comprise a resistance imager 4, a capacitance imager 3, and a temperature sensor 19 and a pressure sensor 18 which are oppositely arranged on the inner wall of the simulation oil pipe 6; the resistance imager 4 is an annular structure with the inner diameter consistent with that of the simulation oil pipe 6, and is formed by annularly arranging 16 electrodes with reference to fig. 2, the four-point method tomography measurement is carried out, namely any two electrodes are used as current excitation electrodes, the voltage value between any other two electrodes is measured, the resistivity field distribution rule in the whole plane is obtained through repeated measurement, and the two ends of the resistance imager 4 are respectively provided with a male buckle and a female buckle which are matched with the simulation oil pipe 6 and are connected to the simulation oil pipe as a connecting piece of the simulation oil pipe 6; referring to fig. 3, the capacitance imager 3 is an annular structure with an inner diameter consistent with that of the oil pipe and is formed by annularly arranging 16 electrodes, one point of an electrode shell is grounded, current is injected from any point, capacitance between the electrode point and other electrode points is measured, capacitance field distribution in the whole plane is obtained through repeated measurement, and a male buckle and a female buckle which can be matched with the simulated oil pipe 6 are respectively arranged at two ends of the capacitance imager 3 and are connected to the simulated oil pipe as a connecting piece of the simulated oil pipe; the resistance imager 4 and the capacitance imager 3 are connected in series on the simulation oil pipe 6 through a connecting collar as shown in fig. 1, and the temperature sensor 19 and the pressure sensor 18 are respectively arranged at the equal height parts of the inner wall of the connecting collar.
The resistance imager acquires 104 resistivity data values once through 16 electrode measurement, the resistivity data values are subjected to certain data imaging forward modeling to obtain a medium distribution state in an electrode measurement plane, a flow pattern and a distribution and aggregation rule of silt in a gas-liquid mixed flow are identified, and the resistance imager requires a continuous phase of a measured medium to be a conductive medium, so that the resistance imager is suitable for measurement of a low gas-liquid ratio shaft flow condition with formation water as the continuous phase; the capacitance imager acquires 120 capacitance value data once by 16 electrode measurement, the capacitance value data values are subjected to certain data imaging forward modeling to obtain a medium distribution state in an electrode measurement plane, and a flow pattern and a distribution and aggregation rule of silt in a gas-liquid mixed flow are identified; the capacitance imager requires the continuous phase of the measured medium to be a conductive medium, so the capacitance imager is suitable for measuring the flow condition of a high gas-liquid ratio shaft with the gas phase as the continuous medium.
In the embodiment, referring to fig. 4, the fluid director 20 is a circular structure formed by combining an upper porous screen plate and a lower porous screen plate, the aperture of the lower porous screen plate 20-2 is larger than that of the upper porous screen plate 20-1, the outer edge of the fluid director 20 is connected with the gas-liquid mixer 9, and the pore size structure of 'big bottom and small top' is beneficial to enabling fluid flowing out of the gas-liquid mixer 9 to rapidly enter the bottom end face of the well, so that the fluid flows into the simulated formation along a direction vertical to the upper simulated formation to form uniform inflow, sand in the upper simulated formation is prevented from being washed away by dominant air holes, and a separate large pore path is formed.
In the gas-liquid injection process, in order to fully mix gas and liquid, a shunting baffle and a turbine stirrer (not shown in the figure) are arranged inside the annular structure of the gas-liquid mixer 9, the shunting baffle enables the injected gas and liquid to be sprayed into the gas-liquid mixer in a rotating manner, and the turbine stirrer rotates at a high speed under the impact action of the water injected into the water injection pipeline, so that the gas and the liquid are fully stirred and mixed; meanwhile, in order to make the temperature of the gas and the liquid on the ground consistent with the bottom temperature of the actual natural gas hydrate production well, the high-pressure gas bottle group 14 further comprises an air bath temperature control device so as to control the temperature of the injected gas according to the bottom temperature of the actual natural gas hydrate production well; the water tank 16 further comprises a water bath temperature control device to control the temperature of the injected liquid according to the bottom temperature of the actual natural gas hydrate production well; and the outer walls of the water injection pipeline 13 and the gas injection pipeline 12 are also wrapped with heat insulation layers so as to ensure that the temperature of the water with the set temperature on the ground is kept unchanged in the process of injecting the water to the bottom of the well, thereby achieving the purpose of simulating the bottom temperature of the actual natural gas hydrate exploitation well.
Through the design of the simulation system of the embodiment, the following functions can be realized: verifying flow patterns and conversion dynamic control factors thereof under different gas-liquid ratios and different temperature and pressure conditions of an actual hydrate production well; observing the aggregation priority rule and the migration process of the shaft mud sand in the gas phase and the liquid phase under different flow pattern conditions; observing the distribution rule of the concentration of the stratum sand in the shaft under the condition of stable flow and the slippage and sedimentation effects in the upward returning process; the critical sand-carrying flow rate and the critical sand-carrying gas-liquid ratio of the shaft under different flow rate conditions and different flow pattern conditions and the maximum sand-carrying particle size under the conditions of a certain flow rate, a certain flow pattern and a certain gas-liquid ratio can be observed; by installing the capacitance imager and the resistance imager at different depth positions in the shaft, observation and quantitative description of the sand-carrying dynamic longitudinal evolution rule in the whole shaft are realized. By developing the mud and sand carrying and moving rule of the shaft under different well structure conditions and establishing the quantitative relation between the mud and sand carrying and moving, gathering dynamic and flow pattern of the shaft, the design basis for the shaft flowing guarantee water injection scheme of the sea natural gas hydrate exploitation well can be provided.
Embodiment 2 provides a simulation method based on the simulation system provided in embodiment 1, and a simulation flow chart of the simulation method based on the simulation system for the sand-carrying law of the wellbore of the marine gas hydrate production well is shown in fig. 5, and includes the following steps:
A. combining the gas-liquid ratio condition of an actual hydrate production well and the size of a shaft oil pipe, and installing a simulated in-well device;
(1) Analyzing a possible gas-liquid ratio range in the natural gas hydrate production well by combining the actual stratum clay content through productivity simulation, and determining the bottom temperature of the natural gas hydrate production well to be simulated according to the stratum temperature and the produced fluid simulation condition;
(2) Circularly controlling the temperature of the high-pressure gas cylinder group and the water tank to ensure that the temperature of gas and liquid on the ground is consistent with the bottom temperature of an actual natural gas hydrate exploitation well, then installing an in-well device, injecting water into the bottom of the well, and circularly controlling the temperature of a bottom structure of the well;
B. injecting fixed gas-liquid ratio, and circularly collecting until a stable shaft flow pattern is formed:
opening a bottom hole test electromagnetic valve, injecting gas and liquid phases into a well according to the determined gas-liquid ratio condition, avoiding simulated formation sand, circulating for a period of time, and judging continuous phases and discontinuous phases in a simulated oil pipe and the distribution relation thereof by a capacitance imager and a resistance imager until a flow pattern in the simulated oil pipe stably exists;
C. adjusting a well bottom flow, carrying sand and producing:
(1) Keeping the ground gas and liquid injection unchanged, closing a bottom hole testing electromagnetic valve, enabling a gas-liquid mixture to flow through simulated formation sand and flow into a simulated oil pipe together with the simulated formation sand, and recording temperature, pressure, capacitance imaging results and resistance imaging results at different well depth positions in real time in the process of the step;
(2) In the sand carrying production process, comparing the capacitance imaging result and the resistance imaging result with the capacitance imaging result and the resistance imaging result under the stable flow pattern condition in the step B, analyzing and simulating the distribution and carrying rules of the sand and mud in the oil pipe in gas-liquid phases, and quantitatively identifying the influence of the sand carrying amount on the shaft flow pattern and the sand carrying and moving rule under different temperature and pressure conditions;
D. obtaining shaft sand carrying dynamic under different flow patterns, finishing the simulation process, and providing a shaft sand carrying flow guarantee proposal, wherein the basic principle that the steps B to C can carry out the simulation of the sand carrying rule under the different flow patterns of the shaft is as follows: in the step B process, resistance imaging and capacitance imaging results are basically maintained to be stable under the condition of stable flow pattern, and large mutation or transition is avoided, in the step C process, as only the bottom hole flow is adjusted and the gas-liquid injection condition of the shaft is kept unchanged, the change of the shaft flow pattern and the change of the resistance imaging and capacitance imaging results under the same flow pattern condition can only be caused by introducing a third mobile phase, namely simulated formation sand, taking slug flow as an example, if the formation sand is mainly distributed in a water phase, the chromatic value of the resistance imaging result is changed, the capacitance imaging result is unchanged, and the larger the chromatic value change is, the larger the sand-carrying concentration is indicated; if the formation silt is mainly distributed in the gas phase, the disturbance of the resistance imaging result is small, but the chroma value of the capacitance imaging result is changed, and the change of the chroma value is larger, which indicates that the concentration of the carried silt is larger; if the formation silt is distributed at the gas-liquid interface, the boundary value of the results of the resistance imaging and the capacitance imaging fluctuates, and the larger the fluctuation is, the larger the silt concentration distributed at the gas-liquid interface is. The sand carrying capacity and the influence thereof on the flow pattern can be quantitatively evaluated according to the size of the colorimetric value disturbance.
Example 3, based on examples 1 and 2, a typical sand-carrying simulation experiment operating process is as follows:
(1) The simulation shaft 2 is a stock part in a test well subsystem, is in a permanent consolidation state with a peripheral stratum through cement, and is drilled into an artificial cement shaft bottom in the well;
(2) Connecting a gas-liquid mixer 9 and a fluid director 20 on the ground, filling simulated formation sand 11 when a test electromagnetic valve F6 is in a normal running state, placing an anti-collapse orifice plate 10 on the upper part of the simulated formation sand 11, and welding the anti-collapse orifice plate 10 and the gas-liquid mixer 9;
(3) Connecting a gas-liquid mixer 9 with a gas injection pipeline 13 and a water injection pipeline 12, butting the upper end of the gas-liquid mixer 9 with a simulation production casing 5, putting the pipe column combination to the bottom of the artificial well according to a pipe column putting program, and setting an oil pipe to pass through a packer 8;
(4) Installing an oil sleeve annulus packer 7 at a shoe position of a simulation oil pipe 6, starting to simulate the oil pipe according to a pipe column running program, and sequentially connecting the oil pipe with a resistance imager 4, a temperature sensor 19, a pressure sensor 18 and a capacitance imager 3 when the running depth of the simulation oil pipe column is respectively 30m and 150m, wherein the temperature sensor 19 and the pressure sensor 18 are especially positioned on the inner pipe wall at the connecting position of the resistance imager 4 and the capacitance imager 3 and are installed oppositely; the final penetration of the simulated oil pipe 6 depends on the position of the anti-collapse orifice plate 10, and the interval of 5m between the pipe shoe and the anti-collapse orifice plate 10 is ensured. Calculating according to the anti-collapse orifice plate 10 and the artificial well bottom 15m, respectively installing a resistance imager 4, a temperature sensor 19, a pressure sensor 18 and a capacitance imager 3 on the simulated oil pipe at about 150m and 30m of the artificial well bottom;
(5) Setting an oil sleeve annulus packer 7, installing a wellhead blowout preventer 1, and finishing the installation of a test well subsystem;
(6) A water tank 16 and an injection pump 17 are connected, a water injection pipeline 13 is connected, a high-pressure gas cylinder group 14 and a gas injection pipeline 12 are connected, a gas-liquid-solid separator 15 and an outlet of the simulation oil pipe 6 are connected, and the gas-liquid-solid separator 15 and the water tank 16, the gas-liquid-solid separator 15 and the high-pressure gas cylinder group 14 are respectively connected;
(7) Opening the high-pressure ball valves F1, F2, F4 and F5, and ensuring that the test electromagnetic valve F6 is in an open state;
(8) Setting a certain gas-liquid ratio, adjusting the opening of a high-pressure gas bottle 14 and the pump frequency of an injection pump 17, and injecting high-pressure gas and water into the test well to enable the pressure in the gas-liquid mixer to rise to a set high-pressure value (such as 4 MPa);
(9) Under the condition that the opening degree of the high-pressure gas cylinder group 14 and the pump frequency of the injection pump 17 in the step (8) are kept unchanged, the high-pressure ball valve F3 is gradually opened to enable the pressure in the gas-liquid mixer to be maintained at a set high pressure value (such as 4 MPa), the circulation flow is stabilized for a period of time (such as 10 min), and the specific stable flow time is judged according to the step (10);
(10) In the circulating injection process of the step (9), simultaneously starting the resistance imager 4, the temperature sensor 19, the pressure sensor 18 and the capacitance imager 3, recording the temperature, the pressure, the resistance imaging graph and the capacitance imaging graph of different parts of the shaft in real time, continuously acquiring until the resistance imaging graph and the capacitance imaging graph do not fluctuate greatly any more, indicating that the shaft flow pattern is basically in a stable state, and judging specific flow patterns (probably slug flow, mist flow and the like) according to the capacitance imaging result and the resistance imaging result, wherein the sampling display interval of the resistance imaging and the capacitance imaging is 1 s;
(11) Controlling to close the testing electromagnetic valve F6, enabling gas-liquid mixed fluid to flow through the fluid director 20 and enter the simulated formation sand 11, enabling the gas-liquid mixture to carry formation sand to flow out of the anti-collapse baffle 10 and enter the simulated oil pipe 6, and keeping the gas-liquid ratio condition in the step (10) consistent, so that the disturbance and the change of a shaft flow pattern are both caused by the flow of shaft sand, which is also the key point for identifying the shaft sand carrying condition based on a resistance imager and a capacitance imager;
(12) Continuing the step (11) until the amount of the mud and sand collected in the gas-liquid-solid three-phase separator 15 at the well head is approximately equal to the amount of the simulated formation sand 11 filled at the well bottom, indicating that the mud and sand at the well bottom are all carried to the well head, and ending the simulation experiment;
(13) And (5) recording the capacitance imaging result, the resistance imaging result, the temperature value and the pressure value at positions 150m and 30m away from the wellhead in the whole process in the steps (10) to (12), judging the change of the shaft flow pattern caused by the carrying of the sand and mud in the whole sand carrying simulation process, and evaluating the aggregation and distribution rules of the shaft sand and mud in the gas-liquid two phases under different flow pattern conditions.
Through the steps, the shaft sand-carrying production process parameters of the hydrate exploitation well can be preferably obtained, a basis is provided for the design of a sand production management system of the natural gas hydrate exploitation well in the sea area of China, and particularly a real-time regulation and control basis is provided for a shaft liquid injection and sand-carrying scheme.
The parameters such as the installation position of the specific measurement component, the size of the oil casing and the running depth designed in the embodiment are not limited to the protection scope of the patent, and the specific installation parameters are listed mainly for describing the instrument installation and test process and more clearly expressing the operation process of high-pressure indirect visual simulation of sand-carrying dynamic simulation of the natural gas hydrate exploitation well shaft, but any simple modification, equivalent change and modification made according to the technical entity of the invention on the embodiment still belong to the protection scope of the technical scheme of the invention.
Claims (7)
1. The simulation system for the sand carrying rule of the shaft of the marine natural gas hydrate production well is characterized by comprising a test well subsystem, a water-gas injection subsystem, a separation subsystem and a shaft monitoring subsystem;
the test well subsystem comprises a simulation shaft, a simulation casing, a simulation oil pipe, a gas-liquid mixer, an anti-collapse orifice plate, a fluid director, a gas injection pipeline and a water injection pipeline, wherein the simulation casing, the simulation oil pipe, the gas-liquid mixer, the anti-collapse orifice plate, the fluid director, the gas injection pipeline and the water injection pipeline are arranged in the simulation shaft; the simulation shaft is a full-size natural gas hydrate exploitation simulation shaft, and a wellhead blowout preventer is arranged at the wellhead of the simulation shaft; the simulation oil pipe is arranged in the simulation sleeve, a common oil pipe with actual on-site dimension is adopted, an oil sleeve annulus packer is installed at a pipe shoe of the simulation oil pipe, and the annular packing of the simulation sleeve and the simulation oil pipe is realized by setting; the gas-liquid mixer is of an annular structure and is arranged at the bottom of the simulated shaft, the upper end of the gas-liquid mixer is provided with a test electromagnetic valve, and the lower end of the gas-liquid mixer is communicated with the fluid director; the simulation sleeve is connected with the gas-liquid mixer, and the outer diameter of the simulation sleeve is equal to the annular inner diameter of the gas-liquid mixer; the anti-collapse hole plate is a round metal porous plate, the outer diameter of the anti-collapse hole plate is the same as the inner diameter of the simulation sleeve, and the anti-collapse hole plate is arranged at a pipe shoe on the inner wall of the simulation sleeve; a space formed by the anti-collapse orifice plate, the fluid director and the air-liquid mixer annulus is a filling space for simulating formation sand; an oil pipe penetrating packer is further installed at the position of a pipe shoe of the simulation casing pipe to seal an annular space between the simulation casing pipe and the wall of the simulation shaft well, a plurality of through holes are uniformly formed in the circumferential direction of the simulation casing pipe, and the through holes are located above the anti-collapse hole plate and below the oil pipe penetrating packer; the gas injection pipeline and the water injection pipeline penetrate through the packer to be connected with the gas-liquid mixer, and check valves are respectively arranged at the joints of the gas injection pipeline and the water injection pipeline with the gas-liquid mixer;
the water-gas injection subsystem is respectively connected with the separation subsystem and the wellhead blowout preventer, the water-gas injection subsystem comprises a high-pressure gas cylinder group and a water tank which are arranged on the ground, the separation subsystem comprises a gas-liquid-solid separator arranged on the ground, the water tank is connected with a water injection pipeline through an injection pump, and the water tank is connected with a liquid path outlet of the gas-liquid-solid separator and is used for injecting water into the simulation shaft and recovering returned circulating water; the high-pressure gas cylinder group is connected with a gas injection pipeline and a gas path outlet of the gas-liquid-solid separator and is used for injecting gas into the simulation shaft and recovering returned gas to realize gas-liquid circulation, a valve F1 is arranged between the high-pressure gas cylinder group and the gas injection pipeline, a valve F2 is arranged between the injection pump and the water injection pipeline, and a valve F3, a valve F4 and a valve F5 are respectively arranged between the gas-liquid-solid separator and the simulation oil pipe as well as between the high-pressure gas cylinder group and the water tank;
the wellbore monitoring subsystem comprises a resistance imager, a capacitance imager, a temperature sensor and a pressure sensor which are oppositely arranged on the inner wall of the simulation oil pipe; the resistance imager is of an annular structure with the inner diameter consistent with that of the simulation oil pipe, and a male buckle and a female buckle which are matched with the simulation oil pipe are respectively arranged at two ends of the resistance imager and are connected to the simulation oil pipe as a connecting piece of the simulation oil pipe; the capacitance imager is of an annular structure with the inner diameter consistent with that of the simulation oil pipe, and a male buckle and a female buckle which can be matched with the simulation oil pipe are respectively arranged at two ends of the capacitance imager and are connected to the simulation oil pipe as a connecting piece of the simulation oil pipe; the resistance imager and the capacitance imager are connected in series on the simulation oil pipe through a connecting coupling, and the temperature sensor and the pressure sensor are respectively arranged at equal height parts of the inner wall of the connecting coupling;
the resistance imager is formed by annularly arranging 16 electrodes, the four-point method tomography measurement is carried out, the capacitance imager is formed by annularly arranging 16 electrodes, one point of an electrode shell is grounded, current is injected from any point, the capacitance between the electrode and other electrode points is measured, the fluid director is of a circular structure formed by combining an upper layer porous screen plate and a lower layer porous screen plate, the aperture of the lower layer porous screen plate is larger than that of the upper layer porous screen plate, and the outer edge of the fluid director is connected with a gas-liquid mixer.
2. The production well shaft sand-carrying law simulation system according to claim 1, characterized in that: the annular structure of the gas-liquid mixer is internally provided with a shunting baffle and a turbine stirrer, the shunting baffle enables injected gas and liquid to be sprayed into the gas-liquid mixer in a rotating mode, and the turbine stirrer rotates at a high speed under the impact action of water injected into a water injection pipeline, so that the gas and the liquid are fully stirred and mixed.
3. The production well shaft sand-carrying law simulation system according to claim 2, characterized in that: the high-pressure gas cylinder group also comprises an air bath temperature control device for controlling the temperature of the injected gas according to the bottom temperature of the actual natural gas hydrate production well.
4. The production well shaft sand-carrying law simulation system according to claim 3, wherein: the water tank comprises a water bath temperature control device so as to control the temperature of the injected liquid according to the bottom temperature of the actual natural gas hydrate production well.
5. The production well shaft sand-carrying law simulation system according to claim 4, wherein: and the water injection pipeline and the gas injection pipeline are also wrapped with a heat insulation layer.
6. The production well shaft sand-carrying law simulation system according to claim 5, wherein: the shaft monitoring subsystems comprise two groups which are respectively arranged on the upper part of the simulation oil pipe and the lower part of the simulation oil pipe.
7. A simulation method of a simulation system of a sand-carrying law of a shaft of a marine natural gas hydrate production well based on any one of claims 1 to 6 is characterized by comprising the following steps:
A. combining the gas-liquid ratio condition of an actual hydrate production well and the size of a shaft oil pipe, and installing a simulated well device;
(1) Analyzing a possible gas-liquid ratio range in the natural gas hydrate production well by combining the actual stratum clay content through productivity simulation, and determining the bottom temperature of the natural gas hydrate production well to be simulated according to the stratum temperature and the produced fluid simulation condition;
(2) Circularly controlling the temperature of the high-pressure gas cylinder group and the water tank to ensure that the temperature of gas and liquid on the ground is consistent with the bottom temperature of an actual natural gas hydrate exploitation well, then installing an in-well device, injecting water into the bottom of the well, and circularly controlling the temperature of a bottom structure of the well;
B. injecting fixed gas-liquid ratio, and circularly collecting until a stable shaft flow pattern is formed:
opening a bottom hole testing electromagnetic valve, injecting gas and liquid phases into a well according to the determined gas-liquid ratio condition, avoiding simulated formation sand, circulating for a period of time, and judging continuous phases and discontinuous phases in a simulated oil pipe and the arrangement relation thereof through a capacitance imager and a resistance imager until a flow pattern in the simulated oil pipe stably exists;
C. adjusting a well bottom flow, carrying sand and producing:
(1) Keeping the ground gas and liquid injection unchanged, closing a bottom hole testing electromagnetic valve, enabling a gas-liquid mixture to flow through simulated formation sand and flow into a simulated oil pipe together with the simulated formation sand, and recording temperature, pressure, capacitance imaging results and resistance imaging results at different well depth positions in real time in the process of the step;
(2) In the sand carrying production process, comparing the capacitance imaging result and the resistance imaging result with the capacitance imaging result and the resistance imaging result under the stable flow pattern condition in the step B, analyzing the distribution and carrying rules of the sand in the simulated oil pipe in gas-liquid phases, and quantitatively identifying the influence of the sand carrying amount on the flow pattern of the simulated oil pipe and the sand carrying and moving rules under different temperature and pressure conditions;
D. and obtaining the shaft sand carrying dynamic state under different flow pattern conditions, and ending the simulation process.
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