CN111551672B - Natural gas hydrate exploitation methane leakage simulation system and method - Google Patents
Natural gas hydrate exploitation methane leakage simulation system and method Download PDFInfo
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- CN111551672B CN111551672B CN202010224790.7A CN202010224790A CN111551672B CN 111551672 B CN111551672 B CN 111551672B CN 202010224790 A CN202010224790 A CN 202010224790A CN 111551672 B CN111551672 B CN 111551672B
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- NMJORVOYSJLJGU-UHFFFAOYSA-N methane clathrate Chemical compound C.C.C.C.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O NMJORVOYSJLJGU-UHFFFAOYSA-N 0.000 title claims abstract description 239
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 179
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- 238000002347 injection Methods 0.000 claims description 75
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- 239000013535 sea water Substances 0.000 claims description 48
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 31
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01D—MEASURING NOT SPECIALLY ADAPTED FOR A SPECIFIC VARIABLE; ARRANGEMENTS FOR MEASURING TWO OR MORE VARIABLES NOT COVERED IN A SINGLE OTHER SUBCLASS; TARIFF METERING APPARATUS; MEASURING OR TESTING NOT OTHERWISE PROVIDED FOR
- G01D21/00—Measuring or testing not otherwise provided for
- G01D21/02—Measuring two or more variables by means not covered by a single other subclass
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- G—PHYSICS
- G05—CONTROLLING; REGULATING
- G05D—SYSTEMS FOR CONTROLLING OR REGULATING NON-ELECTRIC VARIABLES
- G05D23/00—Control of temperature
- G05D23/19—Control of temperature characterised by the use of electric means
- G05D23/1927—Control of temperature characterised by the use of electric means using a plurality of sensors
- G05D23/193—Control of temperature characterised by the use of electric means using a plurality of sensors sensing the temperaure in different places in thermal relationship with one or more spaces
Abstract
According to the system and the method for simulating methane leakage in natural gas hydrate exploitation, the overlying sedimentary layer, the natural gas hydrate reservoir and the underlying gas-liquid mixing layer are constructed in a layered manner through the system, so that the actual geological environment condition of natural gas hydrate storage is more matched; meanwhile, the leading-edge scientific problems of a dynamic mechanism of exploiting methane leakage of the natural gas hydrate, a relation between dynamic evolution of a natural gas hydrate reservoir stratum and methane leakage flux, a migration and conversion mechanism of methane leakage in a settled layer and the like are quantitatively researched through a leakage channel simulation system, the defect that the existing natural gas hydrate exploitation simulation technology can only research various scientific problems and practical application problems related to the natural gas hydrate reservoir stratum and can not research the methane leakage decomposed by the natural gas hydrate is overcome, and the problem that the existing seabed directly observes methane leakage but can not be connected with the decomposition of the underlying actual natural gas hydrate is solved.
Description
Technical Field
The invention relates to the technical field of marine natural gas hydrate development, in particular to a system and a method for simulating methane leakage in natural gas hydrate exploitation.
Background
The natural gas hydrate is a cage-shaped crystalline compound generated from natural gas and water under the conditions of low temperature and high pressure, is like ice and snow in appearance, and can be burnt when meeting fire, and is commonly called as 'combustible ice'. 1m in the Standard State3The natural gas hydrate can release 164-200 m3The natural gas of (1). The natural gas hydrate has extremely high energy density, and the combustion heat value of the unit volume of the natural gas hydrate is 10 times that of coal and 2-5 times that of the traditional natural gas hydrate. More than 90% of natural gas hydrates exist mainly in sediment layers of marine continental shelves in nature and are widely distributed, and the natural gas hydrates are found in at least 116 areas so farThe total natural gas reserve in the former global natural gas hydrate mineral reservoirs is about 1015-1018 standard cubic meters, and the organic carbon accounts for 53.3% of the global organic carbon and is about 2 times of the total carbon of the conventional fossil fuels (petroleum, natural gas and coal) of the earth. Therefore, natural gas hydrate has become a hot spot of the current energy science research as a strategic alternative energy source with great potential in the future.
However, unlike conventional reservoir resources, natural gas hydrates do not have natural traps, are cemented in the sediment pores in solid form, or exist in layers, veins, and chunks, etc. to fill fissures and cavities in the sediment. After the natural gas hydrate is decomposed, the cementation degree of a reservoir is reduced, a large amount of decomposed methane gas is gathered, and fluid flow in the reservoir possibly causes pore overpressure, so that reservoir instability and geological landslide are caused. The temperature and pressure conditions of the natural gas hydrate reservoir are changed after the seabed landslide, and the natural gas hydrate is possibly caused to be decomposed in a wider range in a linkage manner. The leaked methane can further enter overlying sediments, water bodies and even atmosphere to induce environmental ecological problems such as ocean acidification, biological extinction, climate warming and the like.
Over the past four or fifty years, research on natural gas hydrates has been rapidly developed, and the early research mainly focuses on basic physical properties of the natural gas hydrates, exploration of natural gas hydrate reserves and resources, natural gas hydrate exploitation technology and derivative technology thereof, and the like. Compared with field tests, the indoor simulation experiment technology has the advantages of short period, low risk, low cost and strong repeatability. Therefore, as an important means for the fundamental development of natural gas hydrates, indoor simulation techniques for natural gas hydrates have been developed rapidly, but the current indoor simulation experimental techniques mainly focus on basic physical property measurement, formation and decomposition kinetics and thermodynamic parameter experimental research, geochemical parameter experiments and tests, reservoir mechanical parameter measurement and the like of natural gas hydrates, and there are few experimental simulation researches on methane leakage decomposition of natural gas hydrates. At present, natural gas hydrate is not commercially exploited and tried in a large scale, the environmental ecological effect mechanism brought by reservoir methane leakage caused by natural gas hydrate decomposition is not clear, the data base is extremely deficient, and a simulation system and an experimental method for decomposing methane leakage by natural gas hydrate are urgently needed to be established to quantitatively research the environmental ecological effect of decomposing methane leakage by natural gas hydrate.
Disclosure of Invention
The invention provides a simulation system and a simulation method for exploiting methane leakage by using natural gas hydrate, aiming at overcoming the technical defects that the existing experimental simulation research about decomposing methane leakage by using natural gas hydrate is lacked, the environmental ecological effect brought by reservoir methane leakage caused by decomposing natural gas hydrate is unclear, and the data base is lacked.
In order to solve the technical problems, the technical scheme of the invention is as follows:
natural gas hydrate exploitation methane leakage simulation system includes:
the natural gas hydrate reservoir simulation cavity comprises a cavity body and a plurality of simulation layers arranged in the cavity body;
the stratum temperature control system comprises a temperature sensor arranged in the simulation layer, a heat exchange tube arranged in the cavity and a temperature control device arranged on the outer wall of the cavity, wherein the temperature sensor is in signal connection with the temperature control device, and the heat exchange tube is electrically connected with the temperature control device;
the gas-liquid injection system is communicated with the bottom of the cavity;
a production well system disposed inside the cavity;
the production system is connected with the output end of the production well system, and the output end of the production system is connected with the input end of the gas-liquid injection system;
a pressure sensor disposed in the simulation layer;
a displacement sensor disposed in the simulation layer;
the leakage channel simulation system is arranged at the top of the cavity;
and the acquisition control system is electrically connected with the pressure sensor, the temperature control device, the gas-liquid injection system, the production system, the leakage channel simulation system and the displacement sensor.
In the scheme, the system quantitatively researches the leading-edge scientific problems of a dynamic mechanism of exploiting methane leakage of the natural gas hydrate, the relation between dynamic evolution of a natural gas hydrate reservoir stratum and methane leakage flux, a migration and conversion mechanism of methane leakage and the like, overcomes the defects that the existing natural gas hydrate exploitation simulation technology can only research various scientific problems and practical application problems related in the natural gas hydrate reservoir stratum and can not research the methane leakage decomposed by the natural gas hydrate, and simultaneously solves the problem that the existing seabed directly observes methane leakage but can not be connected with the decomposition of the actual natural gas hydrate covered under the seabed.
In the scheme, the cavity is a large-scale simulation cavity with the diameter of 3 meters and the height of 5 meters, in-situ geological layering construction of the sea area natural gas hydrate reservoir can be realized through the system, and the geological environment system simulation requirement in the large-scale natural gas hydrate forming and decomposing process is met. Compared with a small-scale simulation system, the method can more accurately invert seepage rules, heat transfer and mass transfer characteristics in the natural gas hydrate reservoir stratum in the natural gas hydrate formation and decomposition processes, and make up for the defect that the small-scale simulation system is difficult to realize pressure gradient change in the real natural gas hydrate reservoir stratum; meanwhile, the system is used for simulating the formation and decomposition geological environment of the natural gas hydrate, so that the experimental period is effectively shortened, the experimental cost is greatly reduced, the law can be searched through repeated tests, and the risk of the field test on the surrounding ecological environment system is reduced; finally, compared with the existing numerical simulation research means, the method can be developed based on the actual natural gas hydrate deposition sample, the experimental model is closer to the actual state, and the defects that the numerical theory research has more assumed conditions, the parameter conditions are too rational and the like are overcome.
Compared with the existing natural gas hydrate simulation system which only aims at the research of various characteristics related to the formation and decomposition of the natural gas hydrate, the invention firstly provides the simulation and implementation method of methane leakage in the decomposition of the natural gas hydrate, and can carry out quantitative research on the methane leakage mechanism and the leakage behavior characteristics in the decomposition of the natural gas hydrate; compared with the existing natural gas hydrate simulation system which mainly aims at the simulation of a natural gas hydrate reservoir stratum, the invention not only aims at the natural gas hydrate reservoir stratum, but also carries out layered construction and a realization method on an overlying sedimentary layer, the natural gas hydrate reservoir stratum and an underlying gas-liquid mixed layer, thereby being more consistent with the actual geological environment condition of the natural gas hydrate reservoir; thirdly, compared with the situation that the existing submarine methane leakage direct observation research can only guess that the leaked methane comes from the decomposition of the natural gas hydrate at the lower part, the method correlates the methane leakage behavior with the decomposition of the natural gas hydrate, and can directly obtain one hand of data information of the methane leakage caused by the decomposition of the natural gas hydrate.
The leakage channel simulation system comprises an external frame, a plurality of pressure-resistant pipelines, a flow rate adjusting device, a flow rate metering device and a fluid form monitoring device; wherein:
the pressure-resistant pipeline is arranged on the outer frame;
each pressure-resistant pipeline is internally provided with a flow rate regulating device and a flow rate metering device;
the fluid form monitoring device is arranged on the pressure-resistant pipeline;
the input end of the acquisition control system is electrically connected with the output ends of the flow rate metering device and the fluid form monitoring device;
the output end of the acquisition control system is electrically connected with the control ends of the flow rate adjusting device, the flow rate metering device and the fluid form monitoring device.
The pressure-resistant pipeline is of a transparent structure, and the fluid form monitoring device is installed on the outer wall of the transparent pressure-resistant pipeline.
In the scheme, in the running process of the system, the migration behavior of gas-liquid fluid in the pipeline in the channel can be directly observed through the arranged transparent pressure-resistant pipeline and the fluid form monitoring device; the pipeline is provided with vertical and inclined installation modes on the external frame, so that the conditions of a channel containing cracks and a channel without cracks can be fully simulated; by controlling the actions of the flow rate adjusting device, the flow rate metering device and the fluid form monitoring device, the simulation, observation and research of the migration and transformation behaviors of the methane-containing fluid under different leakage rates in the geological channel with natural gas hydrate exploitation leakage are realized.
In the above scheme, the external frame comprises a support rod and connecting surfaces fixedly connected to two ends of the support rod; the connecting surfaces arranged at the two ends of the supporting rod are correspondingly provided with a plurality of connecting holes in the vertical direction; transparent pressure-resistant pipeline both ends are passed through the connecting hole sets up connect on the face, whole frame simple structure easily installs and easily adjusts according to the survey needs of reality. The anti-corrosion rubber ring is arranged in the connecting hole, the transparent pressure-resistant pipeline is inserted in the anti-corrosion rubber ring, and the anti-corrosion rubber ring is arranged in the connecting hole, so that on one hand, the sealing performance of pipeline connection is ensured, on the other hand, the anti-corrosion performance of a system is improved, and the service life of the device is prolonged.
In the above scheme, the transparent pressure-resistant pipeline comprises an inclined pipeline and a straight pipeline; the inclined pipeline and the straight pipeline are both of an organic glass tube structure or a pressure-resistant sapphire tube structure, and the arrangement of the inclined pipeline and the straight pipeline facilitates the simulation of the channel condition containing cracks and the channel condition without cracks by a system; the voltage resistance value of the organic glass tube structure is 10 MPa; the pressure resistance value of the pressure-resistant sapphire pipe structure is 30 MPa.
In the scheme, in the situation of a channel without cracks, sediment or other simulated sediment which actually covers a sedimentary layer is filled in the pipeline to serve as a porous medium, and an anti-blocking device is arranged in the pipeline filled with the porous medium to prevent the pipeline from being blocked due to the migration of the porous medium caused by gas-liquid flow; under the condition of a channel containing fractures, a porous medium is not filled, and the migration behavior of the leaked gas-liquid fluid in a geological fracture channel can be directly simulated and researched.
In the above scheme, the main body of the flow rate regulating device is a PID regulating valve group, the control end of the PID regulating valve group is electrically connected with the output end of the acquisition control system, and the leakage channel simulation system realizes that the automatic opening and closing system regulates the flow rate of the fluid in the passage through the PID regulating valve group. The flow rate metering device adopts a Doppler ultrasonic velocimeter or a turbine flowmeter and is used for metering the actual leaked fluid flow in the pipeline. The fluid form monitoring device adopts high-definition camera equipment, and a control end of the high-definition camera equipment is electrically connected with an output end of the control acquisition control system; the high-definition camera equipment output end is electrically connected with the acquisition control system input end, and the high-definition camera equipment is used for shooting the condition of gas-liquid fluid in the pipeline in real time and observing the migration characteristic and the evolution characteristic of the leaked gas-liquid fluid in the channel.
The simulation layer comprises an overlying sedimentary layer, a natural gas hydrate reservoir and an underlying gas-liquid mixing layer which are sequentially arranged from top to bottom; wherein:
the pressure sensors and the temperature sensors are respectively and uniformly arranged in each simulation layer;
a plurality of displacement sensors are fixed at the bottom of the overlying sedimentary layer at equal intervals and arranged in the natural gas hydrate reservoir;
the heat exchange pipes are fixed at the top of the underlying gas-liquid mixing layer at equal intervals and arranged in the natural gas hydrate reservoir stratum;
the production well system is arranged in the natural gas hydrate reservoir, and the output end of the production well system penetrates through the overlying sedimentary deposit to be connected with the production system.
The temperature control device comprises a temperature controller, a water bath circulating jacket and an external heat exchange unit; wherein:
the water bath circulating jacket is wrapped on the outer wall of the cavity, and pipelines are arranged at the top and the bottom of the water bath circulating jacket and are connected with the external heat exchange unit through the pipelines; the pipeline is provided with an electromagnetic valve;
the electromagnetic valve control end, the external heat exchange unit control end and the heat exchange tube control end are electrically connected with the output end of the temperature controller;
the input end of the temperature controller is electrically connected with the output end of the temperature sensor;
the temperature controller is electrically connected with the acquisition control system to realize information interaction.
The gas-liquid injection system comprises a gas injection subsystem and a liquid injection subsystem; wherein:
the input end of the gas injection subsystem is connected with the output end of the production system;
the control end of the gas injection subsystem is electrically connected with the acquisition control system to realize information interaction;
the output end of the gas injection subsystem is communicated with the bottom of the cavity and is used for injecting gas into the cavity;
the control end of the liquid injection subsystem is electrically connected with the acquisition control system to realize information interaction;
and the output end of the liquid injection subsystem is communicated with the bottom of the cavity and is used for injecting liquid into the cavity.
The gas injection subsystem comprises a high-pressure gas source, an air compressor, a gas booster pump, a buffer container, a first control valve and a gas flowmeter; wherein:
the output end of the high-pressure air source is connected with the input end of the buffer container through the first control valve;
the air compressor is connected with the input end of the buffer container through the gas booster pump;
the output end of the production system is connected with the input end of the buffer container through the first control valve;
the gas flowmeter is arranged at the output end of the buffer container, and the signal output end of the gas flowmeter is electrically connected with the input end of the acquisition control system;
the output end of the buffer container is communicated with the bottom of the cavity through the first control valve;
the high-pressure gas source, the air compressor, the gas booster pump, the first control valve and the control end of the gas flowmeter are electrically connected with the acquisition control system;
the liquid injection subsystem comprises a seawater storage tank, a high-pressure seawater injection pump, a seawater mass flow meter and a second control valve; wherein:
the output end of the seawater storage tank is connected with the input end of the high-pressure seawater injection pump through the second control valve;
the output end of the high-pressure seawater injection pump is provided with the seawater mass flowmeter, and the signal output end of the seawater mass flowmeter is electrically connected with the input end of the acquisition control system;
the output end of the high-pressure seawater injection pump is communicated with the bottom of the cavity through the second control valve;
and the high-pressure seawater injection pump, the seawater mass flow meter and the control end of the second control valve are electrically connected with the acquisition control system.
Wherein the production well system comprises a horizontal production well, a vertical production well and a third control valve; wherein:
the horizontal production well is horizontally disposed in the natural gas hydrate reservoir; the vertical production well is vertically disposed in the natural gas hydrate reservoir;
uniformly arranging perforation holes on the horizontal production well and the vertical production well, wherein the perforation holes wrap a plurality of layers of sand control nets;
the output end of the horizontal production well and the output end of the vertical production well are connected with the input end of the production system through the third control valve;
and the control end of the third control valve is electrically connected with the acquisition control system.
The production system comprises a back pressure subsystem, a gas-liquid-solid three-phase separation device, a water storage tank, a gas collector and a fourth control valve; wherein:
the input end of the back pressure subsystem is connected with the third control valve, and the output end of the back pressure subsystem is connected with the input end of the gas-liquid-solid three-phase separation device;
the liquid output end of the gas-liquid-solid three-phase separation device is connected with the input end of the water storage tank through the fourth control valve;
the gas output end of the gas-liquid-solid three-phase separation device is connected with the input end of the gas collector through the fourth control valve;
the output end of the gas collector is connected with the input end of the buffer container through the first control valve;
the back pressure subsystem and the control end of the fourth control valve are electrically connected with the acquisition control system;
the acquisition control system comprises a processor and a human-computer interaction module, and the human-computer interaction module is electrically connected with the processor to realize information interaction;
the processor is electrically connected with the pressure sensor, the temperature control device, the gas-liquid injection system, the production system, the leakage channel simulation system and the displacement sensor.
The natural gas hydrate exploitation methane leakage simulation method comprises the following steps:
s1: the method comprises the following steps of realizing geological stratification in a natural gas hydrate reservoir simulation cavity, filling seawater in a lower-lying gas-liquid mixed layer, filling silty sediments serving as porous media in the natural gas hydrate reservoir, and filling a calcareous clay layer in an overlying sediment layer;
s2: according to the form and distribution of a leakage channel simulation system arranged according to actual exploration requirements, filling a medium in a channel to simulate the situation of the channel without cracks or filling the medium to simulate the situation of the channel with cracks;
s3: injecting a pre-calculated quantitative methane gas and seawater into the natural gas hydrate reservoir through a gas-liquid injection system, respectively adjusting the temperature and pressure of each layer in the simulation cavity of the natural gas hydrate reservoir, ensuring that the natural gas hydrate forms the required high-pressure and low-temperature environment, and forming the natural gas hydrate;
s4: opening a production well system to perform decompression decomposition on the natural gas hydrate after the saturation of the natural gas hydrate reaches a preset design value; monitoring and recording the temperature and pressure distribution and change conditions of each layer in the decomposition process of the natural gas hydrate in real time through a temperature sensor and a pressure sensor; monitoring and recording the displacement settlement of the natural gas hydrate reservoir in real time through a displacement sensor;
s5: collecting and recording gas production, water production, sand production and speed through a production system; and simultaneously monitoring the leakage amount of the methane-containing fluid in the leakage channel simulation system and the migration behavior characteristics of the leaked fluid in real time until the natural gas hydrate synthesized in the natural gas hydrate reservoir is completely decomposed, and completing the simulation of methane leakage in the natural gas hydrate exploitation.
Compared with the prior art, the technical scheme of the invention has the beneficial effects that:
according to the system and the method for simulating methane leakage in natural gas hydrate exploitation, the overlying sedimentary layer, the natural gas hydrate reservoir and the underlying gas-liquid mixing layer are constructed in a layered manner through the system, so that the actual geological environment condition of natural gas hydrate storage is more matched; meanwhile, the leading-edge scientific problems of a dynamic mechanism of exploiting methane leakage of the natural gas hydrate, a relation between dynamic evolution of a natural gas hydrate reservoir stratum and methane leakage flux, a migration and conversion mechanism of methane leakage in a settled layer and the like are quantitatively researched through a leakage channel simulation system, the defect that the existing natural gas hydrate exploitation simulation technology can only research various scientific problems and practical application problems related to the natural gas hydrate reservoir stratum and can not research the methane leakage decomposed by the natural gas hydrate is overcome, and the problem that the existing seabed directly observes methane leakage but can not be connected with the decomposition of the underlying actual natural gas hydrate is solved.
Drawings
FIG. 1 is a schematic diagram of a natural gas hydrate production methane leak simulation system for leaks in a fracture-free channel;
FIG. 2 is a schematic diagram of a natural gas hydrate production methane leak simulation system for leak-off in a fractured channel;
FIG. 3 is a schematic diagram of the module connections of a methane leak simulation system for natural gas hydrate production;
FIG. 4 is a schematic flow diagram of a method for simulating methane leakage in natural gas hydrate production;
wherein: 1. a natural gas hydrate reservoir simulation cavity; 11. a cavity; 12. a simulation layer; 121. covering a deposition layer; 122. a natural gas hydrate reservoir; 123. an underlying gas-liquid mixing layer; 2. a pressure sensor; 3. a formation temperature control system; 31. a temperature sensor; 32. a temperature control device; 321. a temperature controller; 322. a water bath circulation jacket; 323. an external heat exchanger unit; 324. an electromagnetic valve; 33. a heat exchange pipe; 4. a displacement sensor; 5. a gas-liquid injection system; 51. a gas injection subsystem; 511. a high pressure gas source; 512. an air compressor; 513. a gas booster pump; 514. a buffer container; 515. a first control valve; 516. a gas flow meter; 52. a liquid injection subsystem; 521. a seawater storage tank; 522. a high pressure seawater injection pump; 523. a seawater mass flow meter; 524. a second control valve; 6. a production well system; 61. a horizontal production well; 62. a vertical production well; 63. a third control valve; 7. a production system; 71. a back pressure subsystem; 72. a gas-liquid-solid three-phase separation device; 73. a water storage tank; 74. a gas collector; 75. a fourth control valve; 8. an acquisition control system; 81. a processor; 82. a human-computer interaction module; 9. a leakage path simulation system; 91. an outer frame; 92. a pressure-resistant pipeline; 93. a flow rate regulating device; 94. a flow rate metering device; 95. a fluid form monitoring device; 10. and an alarm device.
Detailed Description
The drawings are for illustrative purposes only and are not to be construed as limiting the patent;
for the purpose of better illustrating the embodiments, certain features of the drawings may be omitted, enlarged or reduced, and do not represent the size of an actual product;
it will be understood by those skilled in the art that certain well-known structures in the drawings and descriptions thereof may be omitted.
The technical solution of the present invention is further described below with reference to the accompanying drawings and examples.
Example 1
As shown in fig. 1, the natural gas hydrate exploitation methane leakage simulation system according to the present invention includes an overburden 121, a natural gas hydrate reservoir 122, an underburden gas-liquid mixing layer 123 disposed in a natural gas hydrate reservoir simulation cavity 1, a leakage channel simulation system 9, a formation temperature control system 3, a pressure sensor 2, a gas-liquid injection system 5, an exploitation well system 6, a displacement sensor 4, a production system 7, an acquisition control system 8, and an alarm device 10.
In the specific implementation process, the leakage channel simulation system 9 is mainly connected with the natural gas hydrate reservoir simulation cavity 1 and the overlying sedimentary stratum and marine environment system, simulates a migration channel of methane leaked from the natural gas hydrate reservoir after natural gas hydrate decomposition, and can adjust leakage flux, measure leakage rate and leakage amount, observe and record the flowing behavior characteristics of leaked fluid. The leak path simulation system 9 mainly includes an outer frame 91, a plurality of pressure-resistant pipes 92, a flow rate adjusting device 93, a flow rate metering device 94, and a fluid form monitoring device 95.
In the specific implementation process, the pressure simulation and monitoring of different geological layers of the natural gas hydrate reservoir 122, the overlying sedimentary layer 121 and the underlying gas-liquid mixing layer 123 are performed through the pressure sensor 2, the formation pressure simulation is realized by injecting required quantitative gas-liquid fluid at different layers according to in-situ geological environment data, the pressure sensor 2 is uniformly arranged at different layers, and the pressure distribution and the change of the formation are monitored in real time.
In the specific implementation process, the formation temperature control system 3 mainly satisfies the temperature simulation and monitoring of different geological layers such as the natural gas hydrate reservoir 122, the overlying sedimentary layer 121, and the underlying gas-liquid mixed layer 123. The formation temperature control system 3 can realize the ground temperature gradient simulation of the real submarine environment, realize the bidirectional temperature control by arranging the temperature control device 32 and the large-scale walk-in low-temperature chamber on the outer wall of the system, and realize the heat exchange tube 33 groups with rated power which are distributed in the natural gas hydrate reservoir 122 at the same time, wherein the temperature control device 32 is composed of a water bath circulation jacket 322 and an external heat exchanger 323 which are wrapped at the periphery and the bottom; meanwhile, the temperature sensors 31 are arranged at different positions of the natural gas hydrate reservoir simulation cavity 1, so that the temperature distribution and change of a geological environment system in the natural gas hydrate forming and decomposing process can be monitored in real time.
In the specific implementation process, firstly, before the natural gas hydrate is formed, the geological stratification construction of the natural gas hydrate reservoir is realized, according to the actual geological exploration result, seawater containing saturated methane gas is filled in the lower-pressure gas-liquid mixed layer 123, argillaceous silty sediment is filled in the natural gas hydrate reservoir 122, artificial quartz sand is filled in the upper settled layer 121, saturated methane water is injected into the upper settled layer 121 to fill pore water, seawater is injected into the marine environment, and the real conditions of the upper settled layer 121 and the marine environment are simulated. Then, 6 pressure-resistant organic glass pipelines with the size of 5 mm are uniformly distributed to serve as a leakage channel simulation system 9, and the channels are filled with silty sediment to simulate the channel condition without cracks.
Then, the synthesis of the natural gas hydrate sample is carried out, and the precalculated quantitative methane gas and seawater are injected into the natural gas reservoir through the gas-liquid injection system 5, the temperature in the natural gas hydrate reservoir is respectively adjusted to be 8 ℃, the temperature of the underlying gas-liquid mixing layer 123 is adjusted to be 9 ℃, and the temperature of the marine environment is adjusted to be 4 ℃. The pressure of the underlying gas-liquid mixed layer 123 is set to 15MPa, and the pressure of the overlying deposition layer 121 is set to 11MPa, so that the high-pressure and low-temperature environment required for forming the natural gas hydrate is ensured, and the actual temperature and pressure distribution of the overlying deposition layer 121 and the underlying gas-liquid mixed layer 123 is ensured. When the pressure of the natural gas hydrate reservoir 122 is about 12MPa, the saturation of the natural gas hydrate reaches the pre-designed value (35%), which indicates that the natural gas hydrate synthesis step is completed. Then natural gas hydrate decomposition and leakage simulation were performed. Firstly, setting a single vertical well depressurization-method mining mode, opening a vertical mining well 62, gradually reducing the pressure of a natural gas hydrate reservoir 122 to 4.5MPa, then mining at constant pressure of 4.5MPa, simultaneously opening a leakage channel simulation system 9, monitoring and recording the temperature and pressure distribution and change conditions of the natural gas hydrate reservoir 122, an overlying sedimentary layer 121 and an underlying gas-liquid mixed layer 123 in the natural gas hydrate decomposition process in real time, monitoring and recording the displacement settlement amount, gas production, water production, sand production amount and speed of the top of the hydrate reservoir in real time, monitoring and recording the leakage amount of methane-containing fluid, migration behavior characteristics of the leakage fluid and the like in the leakage channel simulation system 9 in real time until the natural gas hydrate synthesized in the natural gas hydrate reservoir 122 is completely decomposed, and finishing the leakage behavior.
Example 2
More specifically, on the basis of example 1, as shown in fig. 2, first, before the formation of the natural gas hydrate, the geological stratification of the natural gas hydrate reservoir is realized, according to the actual geological exploration result, the underlying gas-liquid mixed layer 123 is constructed by filling methane gas in the underlying gas-liquid mixed layer 123, the natural gas hydrate reservoir 122 is filled with argillaceous sediments, the overlying sediment layer 121 is filled with calcareous clay, the overlying sediment layer 121 is filled with saturated methane water to fill pore water, and seawater is injected in the marine environment, so as to simulate the actual conditions of the overlying sediment layer 121 and the marine environment. Then, 8 pressure-resistant organic glass pipelines with the size of 3 mm are uniformly distributed to serve as a leakage channel simulation system 9, and the channel condition containing cracks is simulated without filling a medium in the channel.
Then, the synthesis of the natural gas hydrate sample is carried out, and the precalculated quantitative methane gas and seawater are injected into the natural gas reservoir through the gas-liquid injection system 5, and the temperature in the natural gas hydrate reservoir is respectively adjusted to 8.5 ℃, the temperature of the underlying gas-liquid mixing layer 123 is adjusted to 9.5 ℃, and the temperature of the marine environment is adjusted to 4 ℃. The pressure of the underlying gas-liquid mixed layer 123 is set to 14MPa, and the pressure of the overlying deposition layer 121 is set to 10MPa, so that the high-pressure and low-temperature environment required for forming the natural gas hydrate is ensured, and the actual temperature and pressure distribution of the overlying deposition layer 121 and the underlying gas-liquid mixed layer 123 is ensured. When the pressure of the natural gas hydrate reservoir 122 is about 12MPa, the saturation of the natural gas hydrate reaches the pre-designed value (30%), which indicates that the natural gas hydrate synthesis step is completed. Then natural gas hydrate decomposition and leakage simulation were performed. Firstly, setting a production mode of combining single vertical well with horizontal well depressurization and heat injection, firstly opening a vertical production well 62, gradually reducing the pressure of a hydrate reservoir to 4.5MPa, injecting warm saline water with the mass fraction of 3.5% at 40 ℃ through a horizontal production well 61, then performing constant-pressure 4.5MPa production, simultaneously opening a leakage channel simulation system 9, monitoring and recording the temperature and pressure distribution and change conditions of a natural gas hydrate reservoir 122, an overlying gas-liquid deposition layer 121 and an underlying gas-liquid mixing layer 123 in the decomposition process of the natural gas hydrate in real time, monitoring and recording the displacement settlement quantity, gas production, water production, sand production quantity and speed at the top of the natural gas hydrate reservoir 122 in real time, monitoring the leakage quantity of methane-containing fluid in a channel system in real time, the migration behavior characteristics of the leakage fluid and the like until the natural gas hydrate synthesized in the natural gas hydrate reservoir 122 is completely decomposed, the leakage behavior is ended.
Example 3
More specifically, as shown in fig. 1 and 3, the natural gas hydrate exploitation methane leakage simulation system comprises:
the natural gas hydrate reservoir simulation cavity 1 comprises a cavity body 11 and a plurality of simulation layers 12 arranged inside the cavity body 11;
the formation temperature control system 3 comprises a temperature sensor 31 arranged in the simulation layer 12, a heat exchange pipe 33 arranged in the cavity 11 and a temperature control device 32 arranged on the outer wall of the cavity 11, wherein the temperature sensor 31 is in signal connection with the temperature control device 32, and the heat exchange pipe 33 is electrically connected with the temperature control device 32;
the gas-liquid injection system 5 is communicated with the bottom of the cavity 11;
a production well system 6 disposed inside the cavity 11;
the production system 7 is connected with the output end of the production well system 6, and the output end of the production system 7 is connected with the input end of the gas-liquid injection system 5;
a pressure sensor 2 disposed in the simulation layer 12;
a displacement sensor 4 disposed in the simulation layer 12;
the leakage channel simulation system 9 is arranged at the top of the cavity 11;
and the acquisition control system 8 is electrically connected with the pressure sensor 2, the temperature control device 33, the gas-liquid injection system 5, the production system 7, the leakage channel simulation system 9 and the displacement sensor 4.
In the specific implementation process, the dynamic mechanism of exploiting methane leakage of the natural gas hydrate, the relation between dynamic evolution of a natural gas hydrate reservoir stratum and methane leakage flux, the migration and transformation mechanism of methane leakage and other frontier scientific problems are quantitatively researched through the system, the defects that the existing natural gas hydrate exploitation simulation technology can only research various scientific problems and practical application problems related to the natural gas hydrate reservoir stratum and can not research the methane leakage decomposed by the natural gas hydrate are overcome, and meanwhile, the problem that the existing seabed directly observes methane leakage but can not be connected with the decomposition of the underlying actual natural gas hydrate is solved.
More specifically, the leakage pathway simulation system 9 includes an external frame 91, a plurality of pressure-resistant pipes 92, a flow rate adjusting device 93, a flow rate metering device 94, and a fluid form monitoring device 95; wherein:
the pressure-resistant pipe 92 is provided on the outer frame 1;
each pressure-resistant pipeline 92 is internally provided with a flow rate regulating device 93 and a flow rate metering device 94;
the fluid form monitoring device 95 is mounted on the pressure-resistant pipe 92;
the input end of the acquisition control system 8 is electrically connected with the output ends of the flow rate metering device 94 and the fluid form monitoring device 95;
the output end of the acquisition control system 8 is electrically connected with the flow rate adjusting device 93, the flow rate metering device 94 and the control end of the fluid form monitoring device 5.
More specifically, the pressure-resistant pipe 92 is a transparent structure, and the fluid form monitoring device 95 is mounted on the outer wall of the transparent pressure-resistant pipe 2.
In a specific implementation process, when the pressure-resistant pipeline 92 is an opaque pipeline, the fluid form monitoring device 95 is installed inside the pipeline and is used for monitoring the migration behavior of the gas-liquid fluid in the pressure-resistant pipeline 2 in the channel in real time; when the pressure-resistant pipe 92 is a transparent pipe, the fluid form monitoring device 95 is a high-definition fluid form monitoring device, and can be installed on the outer wall of the pipe, so that the gas-liquid fluid migration in the pressure-resistant pipe 92 can be monitored conveniently.
More specifically, the simulation layer 12 comprises an overlying sedimentary deposit 121, a natural gas hydrate reservoir 122 and an underlying gas-liquid mixing layer 123 which are arranged in sequence from top to bottom; wherein:
a plurality of pressure sensors 2 and a plurality of temperature sensors 31 are respectively and uniformly arranged in each simulation layer 12;
a plurality of displacement sensors 4 are fixed at the bottom of the overlying sedimentary deposit 121 at equal intervals and arranged in the natural gas hydrate reservoir 122;
a plurality of heat exchange pipes 32 are fixed on the top of the underlying gas-liquid mixed layer 123 at equal intervals and arranged in the natural gas hydrate reservoir 122;
the production well system 6 is disposed in the natural gas hydrate reservoir 122 with its output connected to the production system 7 through the overburden 121.
In the specific implementation process, the natural gas hydrate is injected into the natural gas hydrate reservoir simulation cavity 1 through the gas-liquid injection system 5 to form the required gas-liquid fluid, then the stratum temperature control system 3 and the pressure sensor 2 are adjusted, the geological environment conditions such as temperature and pressure required by the formation of the natural gas hydrate are simulated in situ, after the required natural gas hydrate sample is formed in a required time period, the exploitation well system 6 and the production system 7 can be opened, the required exploitation mode is used for realizing the processes of natural gas hydrate decomposition, gas-liquid output collection and the like, and in the natural gas hydrate decomposition process, the vertical settlement change of the natural gas hydrate reservoir 122 is monitored in real time through the displacement sensor 4. The invention can realize geological environment system simulation and real-time data acquisition, processing, image output and storage in the natural gas hydrate forming and decomposing process, and can carry out safety monitoring on the surrounding environment in the whole natural gas hydrate forming and decomposing process.
In the specific implementation process, the natural gas hydrate reservoir simulation cavity 1 is a core component, the diameter and the height of the natural gas hydrate reservoir simulation cavity are meter-level, so that the requirements of truly simulating a seepage field, a heat transfer field and a mass transfer field in the natural gas hydrate formation and decomposition process and analyzing the phase change of the natural gas hydrate formation and decomposition process and the heat transfer and mass transfer and gas flow characteristics in the reservoir are met. The inner wall of the natural gas hydrate reservoir simulation cavity 1 has an anti-corrosion function, and the high-pressure, low-temperature and salt-containing environment in which the natural gas hydrate in the sea area exists can be simulated for a long time by using an anti-corrosion stainless steel material or overlaying an anti-corrosion coating on the inner wall.
In the implementation process, the internal dimensions of the gas hydrate reservoir simulation cavity 1 meet the geological stratification construction requirements of the gas hydrate reservoir 122, the overlying sedimentary layer 121 and the underlying gas-liquid mixing layer 123. The gas-liquid injection system 5 mainly fulfills the function of injecting gas and liquid into the gas hydrate reservoir 122 and the underlying gas-liquid commingled layer 123 and the overlying sedimentary layer 121. The amount of gas-liquid fluid such as methane gas, methane-ethane mixture gas, saturated methane liquid, and gas-water mixture is injected into the lower-pressure gas-liquid mixture layer 123 mainly in accordance with the actual situation. In the natural gas hydrate reservoir 122, mainly liquids and gases such as seawater, methane, ethane and the like required for forming the natural gas hydrate, and hot fluids and chemical reagents and the like required for decomposing the natural gas hydrate are injected into the natural gas hydrate reservoir simulation cavity 1 in the natural gas hydrate decomposition process.
In the specific implementation process, the gas-liquid injection system 5 provided by the invention is provided with the interfaces at the top, the bottom and the side wall of the natural gas hydrate reservoir simulation cavity 1, so that the requirements of different gas-liquid injection modes are met, and the key problems of the formation of the natural gas hydrate caused by the change of the gas-liquid injection mode, the heat and mass transfer law of the decomposition of the natural gas hydrate in different injection modes and the like can be researched.
In the specific implementation process, the pressure sensor 2 related to the invention is mainly applied to pressure detection of different geological layers such as an overlying sedimentary layer 121, a natural gas hydrate reservoir 122 and an underlying gas-liquid mixing layer 123; according to the in-situ address environmental data, quantitative gas-liquid fluid required to be injected is injected into each layer, the pressure sensors 2 are arranged at different layers, and the pressure environment change of the bottom layer is monitored in real time.
In the specific implementation process, the displacement sensors 4 are uniformly distributed in the natural gas hydrate reservoir 122, and the displacement settlement amount inside the natural gas hydrate reservoir 122 caused by pressure propagation, gas-liquid flow and the like in the natural gas hydrate decomposition process is monitored in real time.
Wherein, the temperature control device 32 comprises a temperature controller 321, a water bath circulating jacket 322 and an external heat exchanger unit 323; wherein:
the water bath circulating jacket 322 is wrapped on the outer wall of the cavity 11, and pipelines are arranged at the top and the bottom of the water bath circulating jacket 322 and are connected with the external heat exchange unit 323 through the pipelines; the pipeline is provided with an electromagnetic valve 324;
the control end of the electromagnetic valve 324, the control end of the external heat exchanger unit 323 and the control end of the heat exchange tube 33 are electrically connected with the output end of the temperature controller 321;
the input end of the temperature controller 321 is electrically connected with the output end of the temperature sensor 31;
the temperature controller 321 is electrically connected with the acquisition control system 8 to realize information interaction.
In the specific implementation process, the temperature control device 33 mainly satisfies the temperature simulation and monitoring of different geological layers such as the overlying sedimentary layer 121, the natural gas hydrate reservoir 122, the underlying gas-liquid mixed layer 123, and the like. The temperature control device 33 can realize the ground temperature gradient simulation of the seabed environment, and is realized by wrapping the water bath circulating jacket 322 on the outer wall and the bottom of the natural gas hydrate reservoir simulation cavity 1 and arranging the heat exchange tube 33 groups with fixed power in the natural gas hydrate reservoir simulation cavity; the low-temperature environment of the natural gas hydrate reservoir 122 in the natural gas hydrate forming process can be realized, the earth temperature gradient change from top to bottom of the overlying sedimentary deposit 121, the natural gas hydrate reservoir 122, the underlying gas-liquid mixed layer 123 and the like is truly inverted, and the temperature error is controlled within 0.5 ℃ of kilometers. Meanwhile, the natural gas hydrate reservoir 122 and the upper and lower non-environmental systems related by the invention have large volumes and large surface areas, so that the formation temperature change in the decomposition process of the natural gas hydrate can be realized, and the bottom layer temperature cloud change can be really inverted.
More specifically, the gas-liquid injection system 5 includes a gas injection subsystem 51 and a liquid injection subsystem 52; wherein:
the input end of the gas injection subsystem 51 is connected with the output end of the production system 7;
the control end of the gas injection subsystem 51 is electrically connected with the acquisition control system 8 to realize information interaction;
the output end of the gas injection subsystem 51 is communicated with the bottom of the cavity 11 and is used for injecting gas into the cavity;
the control end of the liquid injection subsystem 52 is electrically connected with the acquisition control system 8 to realize information interaction;
the output end of the liquid injection subsystem 52 is communicated with the bottom of the cavity 11 and is used for injecting liquid into the cavity.
More specifically, the gas injection subsystem 51 includes a high-pressure gas source 511, an air compressor 512, a gas booster pump 513, a buffer vessel 514, a first control valve 515, and a gas flow meter 516; wherein:
the output end of the high-pressure air source 511 is connected with the input end of the buffer container 514 through the first control valve 515;
the air compressor 512 is connected with the input end of the buffer container 514 through the gas booster pump 513;
the output end of the production system 7 is connected with the input end of the buffer container 514 through the first control valve 515;
the output end of the buffer container 514 is provided with the gas flowmeter 516, and the signal output end of the gas flowmeter 516 is electrically connected with the input end of the acquisition control system 8;
the output end of the buffer container 514 is communicated with the bottom of the cavity 11 through the first control valve 515;
the control ends of the high-pressure gas source 511, the air compressor 512, the gas booster pump 513, the first control valve 515 and the gas flowmeter 516 are electrically connected with the acquisition control system 8;
the liquid injection subsystem 52 comprises a seawater storage tank 521, a high-pressure seawater injection pump 522, a seawater mass flow meter 523 and a second control valve 524; wherein:
the output end of the seawater storage tank 521 is connected with the input end of the high-pressure seawater injection pump 522 through the second control valve 524;
the output end of the high-pressure seawater injection pump 522 is provided with the seawater mass flow meter 523, and the signal output end of the seawater mass flow meter 523 is electrically connected with the input end of the acquisition control system 8;
the output end of the high-pressure seawater injection pump 522 is communicated with the bottom of the cavity 11 through the second control valve 524;
the control ends of the high-pressure seawater injection pump 522, the seawater mass flow meter 523 and the second control valve 524 are electrically connected with the acquisition control system 8.
In a specific implementation process, the air compressor 512 is used for driving the gas booster pump 513, and the gas booster pump 513 is a boosting component; the gas injection subsystem 51 does not generate gas, and mainly pressurizes the gas in the high-pressure gas source 511 and injects the pressurized gas into the buffer container 514, and then the pressurized gas is injected into the system through the buffer container 514; since the gas pressurization process involves severe pressure fluctuations, a buffer vessel 514 is required to smooth the pressure of the injected gas for metering.
More specifically, the production well system 6 includes a horizontal production well 61, a vertical production well 62, and a third control valve 63; wherein:
the horizontal production well 61 is disposed horizontally in the natural gas hydrate reservoir 122; the vertical production well 62 is vertically disposed in the natural gas hydrate reservoir 122;
the horizontal production well 61 and the vertical production well 62 are uniformly provided with perforations which wrap a plurality of layers of sand control nets;
the output end of the horizontal production well 61 and the output end of the vertical production well 62 are connected with the input end of the production system 7 through the third control valve 63;
and the control end of the third control valve 63 is electrically connected with the acquisition control system 8.
In the specific implementation process, the horizontal production well 61 and the vertical production well 62 with real sizes (the diameter is 89mm) are distributed in the natural gas hydrate reservoir 122 by the production well system 6, the natural gas hydrate can be produced by simulating the combination of a single horizontal well, a single vertical well and a horizontal well, the vertical well and the horizontal well are uniformly provided with perforations, and a plurality of layers of sand prevention nets are wrapped outside the perforations, so that the sand blocking phenomenon at the well hole position in the gas-liquid production process is prevented.
In the specific implementation process, the sand control net is arranged to only prevent larger particles, and sand with smaller particles does not have the risk of blockage and is output to the production system 7 through the horizontal production well 61 and the vertical production well 62.
More specifically, the production system 7 includes a back pressure subsystem 71, a gas-liquid-solid three-phase separation device 72, a water storage tank 73, a gas collector 74 and a fourth control valve 75; wherein:
the input end of the back pressure subsystem 71 is connected with the third control valve 63, and the output end of the back pressure subsystem 71 is connected with the input end of the gas-liquid-solid three-phase separation device 72;
the liquid output end of the gas-liquid-solid three-phase separation device 72 is connected with the input end of the water storage tank 73 through the fourth control valve 75;
the gas output end of the gas-liquid-solid three-phase separation device 72 is connected with the input end of the gas collector 74 through the fourth control valve 75;
the output end of the gas collector 74 is connected with the input end of the buffer container 514 through the first control valve 515;
the control ends of the back pressure subsystem 71 and the fourth control valve 75 are electrically connected with the acquisition control system 8;
the acquisition control system 8 comprises a processor 81 and a human-computer interaction module 82, wherein the human-computer interaction module 82 is electrically connected with the processor 81 to realize information interaction;
the processor 81 is electrically connected with the pressure sensor 2, the temperature control device 32, the gas-liquid injection system 5, the production system 7, the leakage channel simulation system 9 and the displacement sensor 4.
In a specific implementation, the back pressure subsystem 71 is mainly a back pressure valve for controlling the outlet pressure.
In a specific implementation process, the acquisition control system 8 realizes the functions of real-time acquisition, processing, storage, image output and the like of various environmental data information changes of the formation in the natural gas hydrate forming and decomposing process through the processor 81 and the human-computer interaction module 82.
In the specific implementation process, the system is further provided with an alarm device 9 for early warning and forecasting of leakage of combustible substances such as methane in the natural gas hydrate formation and decomposition processes, monitoring of high pressure in the natural gas hydrate reservoir 122 and the like, and safety of the surrounding environment system in the natural gas hydrate formation and decomposition processes is guaranteed.
Example 4
More specifically, as shown in fig. 4, a natural gas hydrate exploitation methane leakage simulation method is provided, which comprises the following steps:
s1: the method comprises the steps of realizing geological layering construction in a natural gas hydrate reservoir simulation cavity 1, filling seawater in a lower-lying gas-liquid mixed layer 123, filling silty sediment serving as a porous medium in a natural gas hydrate reservoir 122, and filling a calcareous clay layer in an overlying sediment layer 121;
s2: according to the form and distribution of a leakage channel simulation system 9 arranged according to actual exploration requirements, filling a medium in a channel to simulate the situation of the channel without cracks or filling the medium to simulate the situation of the channel with cracks;
s3: injecting pre-calculated quantitative methane gas and seawater into the natural gas hydrate reservoir 122 through the gas-liquid injection system 5, respectively adjusting the temperature and pressure of each layer in the simulation cavity 1 of the natural gas hydrate reservoir, ensuring that the natural gas hydrate forms the required high-pressure and low-temperature environment, and forming the natural gas hydrate;
s4: opening the production well system 6 to reduce the pressure of the natural gas hydrate or decompose the natural gas hydrate in other modes after the saturation of the natural gas hydrate reaches a preset design value; the temperature and pressure distribution and change conditions of each layer in the decomposition process of the natural gas hydrate are monitored and recorded in real time through the temperature sensor 31 and the pressure sensor 2; monitoring and recording the displacement settlement of the natural gas hydrate reservoir 122 in real time through a displacement sensor 4;
s5: gas production, water production, sand production and speed are collected and recorded through a production system 7; and simultaneously monitoring the leakage amount of the methane-containing fluid in the leakage channel simulation system 9 and the migration behavior characteristics of the leaked fluid in real time until the natural gas hydrate synthesized in the natural gas hydrate reservoir 122 is completely decomposed, and completing the simulation of methane leakage in the natural gas hydrate exploitation.
It should be understood that the above-described embodiments of the present invention are merely examples for clearly illustrating the present invention, and are not intended to limit the embodiments of the present invention. Other variations and modifications will be apparent to persons skilled in the art in light of the above description. And are neither required nor exhaustive of all embodiments. Any modification, equivalent replacement, and improvement made within the spirit and principle of the present invention should be included in the protection scope of the claims of the present invention.
Claims (8)
1. Natural gas hydrate exploitation methane leakage simulation system is characterized by comprising:
the natural gas hydrate reservoir simulation cavity (1) comprises a cavity body (11) and a plurality of simulation layers (12) arranged inside the cavity body (11);
the formation temperature control system (3) comprises a temperature sensor (31) arranged in the simulation layer (12), a heat exchange pipe (33) arranged in the cavity (11) and a temperature control device (32) arranged on the outer wall of the cavity (11), the temperature sensor (31) is in signal connection with the temperature control device (32), and the heat exchange pipe (33) is electrically connected with the temperature control device (32);
the gas-liquid injection system (5) is communicated with the bottom of the cavity (11);
a production well system (6) disposed inside the cavity (11);
the production system (7) is connected with the output end of the production well system (6), and the output end of the production system (7) is connected with the input end of the gas-liquid injection system (5);
a pressure sensor (2) disposed in the simulation layer (12);
a displacement sensor (4) arranged in the simulation layer (12);
a leakage channel simulation system (9) arranged at the top of the cavity (11);
the acquisition control system (8) is electrically connected with the pressure sensor (2), the temperature control device (32), the gas-liquid injection system (5), the production system (7), the leakage channel simulation system (9) and the displacement sensor (4);
the leakage channel simulation system (9) comprises an external frame (91), a plurality of pressure-resistant pipelines (92), a flow rate adjusting device (93), a flow rate metering device (94) and a fluid form monitoring device (95); wherein:
the pressure-resistant pipe (92) is provided on the outer frame (91);
each pressure-resistant pipeline (92) is internally provided with a flow rate regulating device (93) and a flow rate metering device (94);
the fluid form monitoring device (95) is mounted on the pressure-resistant pipe (92);
the input end of the acquisition control system (8) is electrically connected with the output ends of the flow rate metering device (94) and the fluid form monitoring device (95);
the output end of the acquisition control system (8) is electrically connected with the control ends of the flow rate regulating device (93), the flow rate metering device (94) and the fluid form monitoring device (95);
the simulation process of the natural gas hydrate exploitation methane leakage simulation system specifically comprises the following steps:
s1: the method comprises the steps of realizing geological layering construction in a natural gas hydrate reservoir simulation cavity (1), filling seawater in a submerged gas-liquid mixed layer (123), filling silty sediment serving as a porous medium in a natural gas hydrate reservoir (122), and filling a calcareous clay layer in an overlying sediment layer (121);
s2: according to the form and distribution of a leakage channel simulation system (9) laid according to actual exploration requirements, filling a medium in a channel to simulate the situation of the channel without cracks or filling the medium to simulate the situation of the channel with cracks;
s3: injecting pre-calculated quantitative methane gas and seawater into the natural gas hydrate reservoir (122) through a gas-liquid injection system (5), respectively adjusting the temperature and pressure of each layer in the natural gas hydrate reservoir simulation cavity (1), ensuring that the natural gas hydrate forms the required high-pressure and low-temperature environment, and forming the natural gas hydrate;
s4: when the saturation of the natural gas hydrate reaches a preset design value, opening a production well system (6) to reduce the pressure of the natural gas hydrate or decompose the natural gas hydrate in other modes; the temperature and pressure distribution and change conditions of each layer in the decomposition process of the natural gas hydrate are monitored and recorded in real time through a temperature sensor (31) and a pressure sensor (2); monitoring and recording the displacement settlement of the natural gas hydrate reservoir (122) in real time through a displacement sensor (4);
s5: gas production, water production, sand production and sand production rate are collected and recorded through a production system (7); and simultaneously, monitoring the leakage amount of the methane-containing fluid in the leakage channel simulation system (9) and the migration behavior characteristics of the leaked fluid in real time until the natural gas hydrate synthesized in the natural gas hydrate reservoir (122) is completely decomposed, and completing the simulation of the methane leakage during the exploitation of the natural gas hydrate.
2. A natural gas hydrate production methane leak simulation system according to claim 1, wherein the pressure-resistant pipe (92) is of a transparent structure, and the fluid form monitoring device (95) is installed on an outer wall of the transparent pressure-resistant pipe (92).
3. A natural gas hydrate production methane leak simulation system according to claim 1, wherein the simulation layer (12) comprises an overlying sedimentary layer (121), a natural gas hydrate reservoir (122) and an underlying gas-liquid mixing layer (123) arranged in this order from top to bottom; wherein:
the pressure sensors (2) and the temperature sensors (31) are respectively and uniformly arranged in each simulation layer (12);
the displacement sensors (4) are fixed at the bottom of the overlying sedimentary deposit (121) at equal intervals and arranged in the natural gas hydrate reservoir (122);
the heat exchange pipes (33) are fixed on the top of the underlying gas-liquid mixing layer (123) at equal intervals and are arranged in the natural gas hydrate reservoir (122);
the production well system (6) is disposed in the natural gas hydrate reservoir (122) with its output connected to the production system (7) through the overburden (121).
4. The natural gas hydrate production methane leak simulation system according to claim 1, wherein the temperature control device (32) comprises a temperature controller (321), a water bath circulation jacket (322) and an external heat exchanger unit (323); wherein:
the water bath circulation jacket (322) is wrapped on the outer wall of the cavity (11), pipelines are arranged at the top and the bottom of the water bath circulation jacket (322) and are connected with the external heat exchange unit (323) through the pipelines; an electromagnetic valve (324) is arranged on the pipeline;
the control end of the electromagnetic valve (324), the control end of the external heat exchanger unit (323) and the control end of the heat exchange tube (33) are electrically connected with the output end of the temperature controller (321);
the input end of the temperature controller (321) is electrically connected with the output end of the temperature sensor (31);
the temperature controller (321) is electrically connected with the acquisition control system (8) to realize information interaction.
5. A natural gas hydrate production methane leak simulation system according to claim 3, wherein the gas-liquid injection system (5) comprises a gas injection subsystem (51) and a liquid injection subsystem (52); wherein:
the input end of the gas injection subsystem (51) is connected with the output end of the production system (7);
the control end of the gas injection subsystem (51) is electrically connected with the acquisition control system (8) to realize information interaction;
the output end of the gas injection subsystem (51) is communicated with the bottom of the cavity (11) and is used for injecting gas into the cavity;
the control end of the liquid injection subsystem (52) is electrically connected with the acquisition control system (8) to realize information interaction;
the output end of the liquid injection subsystem (52) is communicated with the bottom of the cavity (11) and is used for injecting liquid into the cavity.
6. The natural gas hydrate production methane leak simulation system according to claim 5, wherein the gas injection subsystem (51) comprises a high pressure gas source (511), an air compressor (512), a gas booster pump (513), a buffer vessel (514), a first control valve (515), and a gas flow meter (516); wherein:
the output end of the high-pressure air source (511) is connected with the input end of the buffer container (514) through the first control valve (515);
the air compressor (512) is connected with the input end of the buffer container (514) through the gas booster pump (513);
the output end of the production system (7) is connected with the input end of the buffer container (514) through the first control valve (515);
the gas flowmeter (516) is arranged at the output end of the buffer container (514), and the signal output end of the gas flowmeter (516) is electrically connected with the input end of the acquisition control system (8);
the output end of the buffer container (514) is communicated with the bottom of the cavity (11) through the first control valve (515);
the control ends of the high-pressure gas source (511), the air compressor (512), the gas booster pump (513), the first control valve (515) and the gas flowmeter (516) are electrically connected with the acquisition control system (8);
the liquid injection subsystem (52) comprises a seawater storage tank (521), a high-pressure seawater injection pump (522), a seawater mass flow meter (523) and a second control valve (524); wherein:
the output end of the seawater storage tank (521) is connected with the input end of the high-pressure seawater injection pump (522) through the second control valve (524);
the output end of the high-pressure seawater injection pump (522) is provided with the seawater mass flow meter (523), and the signal output end of the seawater mass flow meter (523) is electrically connected with the input end of the acquisition control system (8);
the output end of the high-pressure seawater injection pump (522) is communicated with the bottom of the cavity (11) through the second control valve (524);
the high-pressure seawater injection pump (522), the seawater mass flow meter (523) and the control end of the second control valve (524) are electrically connected with the acquisition control system (8).
7. A natural gas hydrate production methane leak simulation system according to claim 6, wherein the production well system (6) comprises a horizontal production well (61), a vertical production well (62) and a third control valve (63); wherein:
the horizontal production well (61) is disposed horizontally in the natural gas hydrate reservoir (122); the vertical production well (62) is vertically disposed in the natural gas hydrate reservoir (122);
uniformly arranging perforation holes on the horizontal production well (61) and the vertical production well (62), wherein the perforation holes wrap a plurality of layers of sand control nets;
the output end of the horizontal production well (61) and the output end of the vertical production well (62) are connected with the input end of the production system (7) through the third control valve (63);
and the control end of the third control valve (63) is electrically connected with the acquisition control system (8).
8. The natural gas hydrate production methane leak simulation system according to claim 7, wherein the production system (7) comprises a back pressure subsystem (71), a gas-liquid-solid three-phase separation device (72), a water storage tank (73), a gas collector (74) and a fourth control valve (75); wherein:
the input end of the back pressure subsystem (71) is connected with the third control valve (63), and the output end of the back pressure subsystem (71) is connected with the input end of the gas-liquid-solid three-phase separation device (72);
the liquid output end of the gas-liquid-solid three-phase separation device (72) is connected with the input end of the water storage tank (73) through the fourth control valve (75);
the gas output end of the gas-liquid-solid three-phase separation device (72) is connected with the input end of the gas collector (74) through the fourth control valve (75);
the output end of the gas collector (74) is connected with the input end of the buffer container (514) through the first control valve (515);
the control ends of the back pressure subsystem (71) and the fourth control valve (75) are electrically connected with the acquisition control system (8);
the acquisition control system (8) comprises a processor (81) and a human-computer interaction module (82), wherein the human-computer interaction module (82) is electrically connected with the processor (81) to realize information interaction;
the processor (81) is electrically connected with the pressure sensor (2), the temperature control device (32), the gas-liquid injection system (5), the production system (7), the leakage channel simulation system (9) and the displacement sensor (4).
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| CN113356800B (en) * | 2021-06-28 | 2022-09-09 | 西南石油大学 | Experimental device and method for combined exploitation of marine hydrate and free gas |
| CN113686497B (en) * | 2021-07-14 | 2022-08-16 | 大连理工大学 | Visual experimental device for researching pipeline flowing safe hydrate characteristics and leakage monitoring |
| CN113898337A (en) * | 2021-09-24 | 2022-01-07 | 中国矿业大学 | Interaction model of hydrate exploitation shaft and sedimentary deposit and use method thereof |
| CN114577995B (en) * | 2022-03-15 | 2022-11-15 | 南方海洋科学与工程广东省实验室(广州) | Deep-sea methane leakage area continuous process simulation device and methane circulation characterization method |
| CN115824894A (en) * | 2022-12-21 | 2023-03-21 | 南通辰聚电子科技有限公司 | Experimental device and experimental method for researching natural gas leakage diffusion law in limited space |
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| CN105372392B (en) * | 2015-10-30 | 2017-02-15 | 中国科学院力学研究所 | Simulation experiment device for methane gas leakage caused by natural gas hydrate decomposition |
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