CN112240186A - Natural gas hydrate heat injection-replacement combined simulation mining device and method - Google Patents
Natural gas hydrate heat injection-replacement combined simulation mining device and method Download PDFInfo
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- CN112240186A CN112240186A CN201910649405.0A CN201910649405A CN112240186A CN 112240186 A CN112240186 A CN 112240186A CN 201910649405 A CN201910649405 A CN 201910649405A CN 112240186 A CN112240186 A CN 112240186A
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- 238000000034 method Methods 0.000 title claims abstract description 56
- 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 25
- 238000005065 mining Methods 0.000 title claims description 18
- 238000004088 simulation Methods 0.000 title abstract description 5
- 239000007789 gas Substances 0.000 claims abstract description 143
- 238000006243 chemical reaction Methods 0.000 claims abstract description 108
- 238000006073 displacement reaction Methods 0.000 claims description 20
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 20
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 16
- 239000006004 Quartz sand Substances 0.000 claims description 13
- 239000000843 powder Substances 0.000 claims description 13
- 238000001514 detection method Methods 0.000 claims description 12
- 238000004519 manufacturing process Methods 0.000 claims description 7
- 239000000203 mixture Substances 0.000 claims description 7
- 238000000354 decomposition reaction Methods 0.000 claims description 6
- 230000035484 reaction time Effects 0.000 claims description 5
- 238000005259 measurement Methods 0.000 claims description 3
- 239000004576 sand Substances 0.000 claims description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 16
- 238000004817 gas chromatography Methods 0.000 description 6
- 239000007924 injection Substances 0.000 description 6
- 238000002347 injection Methods 0.000 description 6
- 239000003153 chemical reaction reagent Substances 0.000 description 3
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 239000007795 chemical reaction product Substances 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 239000002803 fossil fuel Substances 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
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- 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
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
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- 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
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
- E21B43/168—Injecting a gaseous medium
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- Mining & Mineral Resources (AREA)
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- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
Abstract
The invention provides a natural gas hydrate heat injection-replacement combined simulation exploitation device and a method. The device comprises: gas replacement cylinder (1), CH4The system comprises a gas cylinder (25), a first gas flowmeter (3), a second gas flowmeter (17), a heater (4), a temperature control device (13), a reaction kettle (11), a data acquisition instrument (15) and a computer (16); the reaction kettle (11) is arranged in the temperature control device (13) to control the temperature in the reaction container through the temperature control device, the replacement gas cylinder (1), the first gas flowmeter (3), the heater (4) and the reaction kettle (11) are sequentially connected through a first pipeline (26), and CH4The gas cylinder (25), the second gas flowmeter (17) and the reaction kettle (11) are sequentially connected through a second pipeline (27), and the data acquisition instrument (15) is electrically connected with the reaction kettle (11) and the computer (16) respectively.
Description
Technical Field
The invention relates to the field of natural gas hydrate development, in particular to a natural gas hydrate heat injection-replacement combined simulation mining device and method.
Background
Natural gas hydrate is a clean energy resource with a carbon content equivalent to 2 times the sum of conventional fossil fuels worldwide. At present, the exploitation of natural gas hydrate has important economic and environmental benefits, and the traditional natural gas exploitation methods at present mainly comprise a depressurization method, a heat injection method, a chemical reagent method or a combination of the two methods. Compared with a single exploitation method, the combined exploitation method can be beneficial to exploitation of the natural gas hydrate to a certain extent.
The existing method for jointly exploiting the natural gas hydrate mainly comprises a heat injection and depressurization method, a replacement and depressurization method, a heat injection and chemical reagent method, a depressurization and chemical reagent method and the like. The replacement method is a high-quality method for simultaneously sealing and storing gas and exploiting energy in a single exploitation method, but the replacement efficiency is low, the heat injection method has quick response and high cost, and the replacement exploitation efficiency can be improved by combining the replacement method and the heat injection method for combined exploitation.
Disclosure of Invention
One object of the invention is to provide a natural gas hydrate heat injection-replacement combined simulation exploitation device; the device provided by the invention realizes that the hydrate is exploited by gas replacement assisted heat replacement on the basis of hydrate generation, the replacement rate and the replacement rate are improved, and the device is simple and easy to operate, simple in structure and low in cost.
The invention also aims to provide a natural gas hydrate heat injection-displacement combined mining method.
In order to achieve the above object, in one aspect, the present invention provides a gas hydrate heat injection-displacement combined simulated production apparatus, wherein the apparatus comprises: gas replacement cylinder 1, CH4The system comprises a gas cylinder 25, a first gas flow meter 3, a second gas flow meter 17, a heater 4, a temperature control device 13, a reaction kettle 11, a data acquisition instrument 15 and a computer 16; the reaction kettle 11 is arranged in the temperature control device 13 to control the temperature in the reaction container through the temperature control device, the replacement gas cylinder 1, the first gas flowmeter 3, the heater 4 and the reaction kettle 11 are sequentially connected through a first pipeline 26, and CH4The gas cylinder 25, the second gas flowmeter 17 and the reaction kettle 11 are sequentially connected through a second pipeline 27, and the data acquisition instrument 15 is respectively connected with the reaction kettle 11 and the flowmeterThe computer 16 is electrically connected.
According to some embodiments of the invention, the second gas meter 17 is a wet gas meter.
According to some embodiments of the present invention, the temperature control device 13 is a constant temperature water tank.
According to some embodiments of the invention, the heater 4 is an air heater.
According to some embodiments of the present invention, the reaction kettle 11 includes a kettle body 29, a kettle cover 28 disposed on the top of the kettle body 29, a gas inlet/outlet 9 disposed on the kettle cover 28, and a sand outlet 14 disposed on the bottom of the kettle body 29; the kettle cover 28 is provided with a pressure detection interface 26 and a temperature detection interface 27 which are connected to the inner cavity of the kettle body 29, and the coil pipe 12 extends into the inner cavity of the kettle body 29 through the gas inlet and outlet 9.
According to some embodiments of the invention, the kettle cover and the kettle body are connected through threads or flanges.
According to some embodiments of the present invention, the reaction vessel 11 further comprises a support 30 disposed at the bottom of the vessel 29 for supporting the vessel 29.
According to some specific embodiments of the present invention, the reaction vessel 11 further comprises a pressure sensor 18 electrically connected to the pressure detection interface 26 and a temperature sensor 10 disposed at the temperature detection interface 27; the pressure sensor 18 and the temperature sensor 10 are respectively electrically connected with the data acquisition instrument 15.
According to some embodiments of the invention, the height of the coil 12 is 1/4-1/2 of the height of the inner cavity of the reaction kettle; the diameter is 0.25-0.75 of the diameter of the inner cavity of the reaction kettle; the spiral diameter of the coil is 0.25-0.75 times of the inner diameter of the reaction kettle.
It is to be understood that the spiral diameter of the coil pipe in the present invention refers to the diameter of a circle formed by the projection of the spiral part of the coil pipe on a horizontal plane passing through any point on the spiral part.
According to some embodiments of the present invention, the coil 12 is provided with air holes 121, and the distance between any two adjacent air holes is 0.2 to 0.8 times the outer diameter of the coil pipe.
The air holes 121 enable the inner cavity of the coil to be communicated with the outside.
According to some embodiments of the invention, the apparatus further comprises a replacement gas pressure reducing valve 2 disposed in the line between the replacement gas cylinder 1 and the first gas flow meter 3, and a gas pressure regulator disposed at CH4CH on the line between gas cylinder 25 and second gas flow meter 174A pressure relief valve 24.
According to some embodiments of the present invention, the apparatus further comprises a second three-way valve 20, a third three-way valve 22, a first stop valve 7, a second stop valve 19, a third stop valve 23; a second cut-off valve 19, a second three-way valve 20, a third three-way valve 22, and a third cut-off valve 23 are provided in the second gas flow meter 17 and the CH in this order from the second gas flow meter 174The first stop valve 7 is provided in the line between the heater 4 and the reaction tank 11 in the line between the pressure reducing valves 24.
According to some specific embodiments of the present invention, the apparatus further comprises a first hydraulic pressure gauge 5 and a second hydraulic pressure gauge 21; the first hydraulic pressure gauge 5 is provided on the heater 4, and the second hydraulic pressure gauge 21 is provided on the third three-way valve 22.
According to some embodiments of the present invention, the apparatus further comprises a first three-way valve 8, the first three-way valve 8 is disposed on the pipeline between the first stop valve 7 and the reaction vessel 11, and the second pipeline 27 is connected to the reaction vessel 11 through the first three-way valve 8.
On the other hand, the invention also provides a natural gas hydrate heat injection-displacement combined simulated exploitation method, wherein the method comprises the steps of introducing methane into a reaction kettle filled with ice powder and quartz sand to generate a hydrate; after the hydrate is formed, the displacement reaction is carried out by introducing heated displacement gas.
According to some embodiments of the invention, the mass ratio of the ice powder to the quartz sand is 0.5: 1-1: 0.5.
according to some embodiments of the present invention, the method comprises feeding methane into a reaction kettle containing ice powder and quartz sand, and controlling the feeding pressure in the reaction kettle to be more than 3MPa until no methane is consumed.
According to some embodiments of the present invention, the method comprises feeding methane into a reaction kettle containing ice powder and quartz sand, and controlling the feeding pressure to be 3-20 MPa.
According to some embodiments of the present invention, the method comprises feeding methane into a reaction kettle containing ice powder and quartz sand, and controlling the feeding pressure to be 15-20 MPa.
According to some embodiments of the invention, the method comprises using the device of the invention, comprising the steps of:
(1) adding quartz sand and ice powder into a reaction kettle 11, vacuumizing, and opening CH4A pressure reducing valve 24, a third stop valve 23 and a second stop valve 19, and CH is filled in the reaction kettle 114Measuring CH filled in the reaction vessel by a second gas flowmeter 174Measuring, recording CH filled in the reaction kettle4Has a gas volume of V1Opening a temperature control device 13 (constant-temperature water tank) and observing the generated hydrate;
(2) when the pressure in the reaction kettle reaches 5-25 MPa, closing CH4A pressure reducing valve 24, a first cut-off valve 7, a second cut-off valve 19, and a third cut-off valve 23 for charging the replacement gas into the heater 4;
(3) when the pressure and the temperature in the reaction kettle 11 are not changed any more, the second stop valve 19 is opened to remove the unreacted CH in the reaction kettle 114Gas exhaust and wet mass flow meter measurement of exhausted CH4Volume, recording volume V2Recording the pressure indication of the heater 4 reaching the set temperature;
(4) closing the second stop valve 19, opening the first stop valve 7, filling the replacement gas in the heater 4 into the reaction kettle 11, closing the first stop valve 7, and simultaneously adjusting the temperature of the temperature control device 13 to be the set temperature;
(5) the reaction time is 70 h-200 h, and the gas components in the reaction kettle 11 are measured every 2-6 hours until the measured CH4The content of (A) is constant;
(6) when CH is present4When the content is not changed any more, the temperature of the temperature control device 13 is raised to ensure that the reaction product is reactedThe hydrate is completely decomposed, the second stop valve 19 is opened, and the volume V of the replacement gas generated after the decomposition of the residual hydrate is measured with a wet mass flow meter3And measuring the composition of the decomposed gas to determine CH in the displaced gas4The proportion of gas is yCH4And by constant CH determined in step (6)4Comparing the contents to obtain final natural gas hydrate production rate data;
(7) data are sorted and calculated, and the final mining rate eta in the process is:
according to some embodiments of the present invention, step (1) comprises charging CH into reaction vessel 114Until the pressure in the reaction kettle 11 is 6MPa to 12 MPa.
According to some embodiments of the present invention, step (1) comprises opening temperature control device 13 (thermostatic water tank), and setting temperature of temperature control device 13 at-9 deg.C to 2 deg.C.
According to some embodiments of the present invention, the temperature of the heater 4 in the step (2) is set to 105 ℃ to 300 ℃.
According to some embodiments of the present invention, in the step (4), the first stop valve 7 is closed after the pressure of the replacement gas charged into the reaction vessel 11 reaches 10MPa to 16 MPa.
According to some embodiments of the present invention, in the step (4), the temperature of the temperature control device 13 is adjusted to 1 ℃ to 4 ℃.
According to some embodiments of the present invention, step (6) is raising the temperature of temperature control device 13 to 25-50 deg.C; preferably to 30 deg.c.
According to some embodiments of the invention, the replacement gas is a gas comprising CO2Based on the total volume of the displacement gas as 100%, CO2The content of the volume percent is 15-100%.
According to some embodiments of the invention, wherein the displacement gas is N2/CO2MixingGas or CO2。
According to some embodiments of the invention, wherein the displacement gas is N2/CO2Mixed gas of N2And CO2Is 1: (0.05-100),
according to some embodiments of the invention, the method comprises the steps of:
(1) adding a certain amount of quartz sand and ice powder into a reaction kettle, vacuumizing, and opening CH4A pressure reducing valve, a third stop valve and a second stop valve, and CH is filled in the reaction kettle4Measuring CH filled in the reaction kettle by a wet mass flowmeter until the pressure is 6-12 MPa4Measuring, recording CH filled in the reaction kettle4Has a gas volume of V1Opening a temperature control device 13 (a constant-temperature water tank), and setting the temperature of the temperature control device 13 to be-9-2 ℃;
(2) closing CH when hydrate is formed4The pressure reducing valve, the first stop valve, the second stop valve and the third stop valve charge the replacement gas into the air heater, and the temperature of the air heater is set to be 105-300 ℃;
(3) when the readings of the pressure sensor and the temperature sensor are not changed any more, namely after the hydrate is generated, the second stop valve is opened, and the CH for reaction in the reactor is4Gas exhaust and wet mass flow meter measurement of exhausted CH4Volume, recording volume V2Recording the pressure indication of the air heater reaching the set temperature;
(4) closing the second stop valve, opening the first stop valve, filling the replacement gas in the air heater into the reaction kettle through the gas injection port and the first three-way valve, closing the first stop valve when the pressure of the replacement gas filled into the reaction kettle reaches 10-16 MPa, and simultaneously adjusting the temperature of a temperature control device 13 (a constant-temperature water tank) to be 1-4 ℃; wherein in the displacing gas, CO2And N2The volume ratio of (A) to (B) is 0.2 to 4;
(5) the reaction time is 70 h-200 h, and the gas components are measured by gas chromatography every 2-6 hours until the measured CH4The content of (A) is constant;
(6) when CH is present4When the content no longer changes, the temperature of the temperature control device 13 (constant temperature water tank) is raised to completely decompose the reacted hydrate, the second stop valve is opened, and the volume V of the replacement gas generated after the decomposition of the residual hydrate is measured by a wet mass flow meter3And measuring the composition of the decomposed gas by gas chromatography to obtain CH in the displaced gas4The proportion of gas is yCH4And by constant CH measured in step 64Comparing the contents to obtain final natural gas hydrate production rate data;
(7) data are sorted and calculated, and the final mining rate eta in the process is:
in summary, the invention provides a natural gas hydrate heat injection-displacement combined exploitation device and a method. The device and the method have the following advantages:
1, a coil pipe with holes is inserted into the reaction kettle, so that the gas-solid contact area is increased, the generation of methane hydrate is accelerated, and the reaction of the displaced gas and the generated hydrate is facilitated in the displacement process, thereby improving the recovery rate of methane.
2, adopting a method of heat injection-replacement gas replacement to recover the hydrate, and providing a reaction channel for the replacement gas to enter the interior of the hydrate by virtue of the heat transfer property of the gas.
Drawings
Fig. 1 is a schematic diagram of an experimental device for gas hydrate heat injection-displacement combined exploitation.
FIG. 2 is a sectional view of a reaction vessel.
Detailed Description
The following detailed description is provided for the purpose of illustrating the embodiments and the advantageous effects thereof, and is not intended to limit the scope of the present disclosure.
Example 1
Gas hydrate heat injection-displacement combined simulated exploitation as shown in figure 1Experimental set-up including replacement gas (CO)2/N2) Gas cylinder 1, CH4The system comprises a gas cylinder 25, a first gas flowmeter 3, a wet gas flowmeter 17, an air heater 4, a constant-temperature water tank 13, a reaction kettle 11, a data acquisition instrument 15 and a computer 16; the reaction kettle 11 is connected with the air heater 4, the gas flowmeter 3 and the replacement gas cylinder 1 in sequence; the constant-temperature water tank 13 is arranged outside the reaction kettle 11; the CH4The gas cylinder 25 is connected to the wet gas flowmeter 17 and the reaction vessel 11 in this order. As shown in fig. 2, the reaction kettle 11 includes a kettle body 29, a kettle cover 28 disposed on the top of the kettle body 29, a gas inlet/outlet 9 disposed on the kettle cover 28, a support 30 supporting the bottom of the kettle body 29, and a sand outlet 14 disposed on the bottom of the kettle body 29. The kettle cover 28 is provided with a pressure detection interface 26, a temperature detection interface 27 and a coil pipe 12 which can be connected to the inner cavity of the kettle body 29. The coil 12 is disposed in the gas inlet/outlet 9. The height of the coil pipe 12 is 1/2 of the height of the inner cavity of the reaction kettle; the diameter is 0.5 of the diameter of the inner cavity of the reaction kettle; the spiral diameter of the coil is 0.5 times of the inner diameter of the reaction kettle. The coil pipe 12 is provided with air holes 121, and the distance between any two adjacent air holes is 0.5 times of the pipe diameter of the coil pipe. The kettle cover 28 is connected with the kettle body 2 through threads or flanges. Also comprises a temperature sensor 10 and a pressure sensor 18; the temperature sensor 10 is connected to a temperature measuring interface of the reaction kettle 11; the pressure sensor 18 is connected to a pressure detection port of the reaction kettle 11; the sensors are connected with a data acquisition instrument 15 through signal wires, the data acquisition instrument 15 is connected with a computer 16, and the computer displays the readings of all temperatures and pressures; and also includes CH4Pressure reducing valve 24, replacement gas (CO)2/N2) The hydraulic control system comprises a pressure reducing valve 2, a first hydraulic gauge 5, a second hydraulic gauge 21, a first three-way valve 8, a second three-way valve 20, a third three-way valve 22, a first stop valve 7, a second stop valve 19 and a third stop valve 23; the CH4The pressure reducing valve 24 is arranged at CH4The pipeline connected between the gas cylinder 25 and the wet gas flowmeter 17; the replacement gas (CO)2/N2) The pressure reducing valve 2 is arranged in the replacement gas (CO)2/N2) The pipeline is connected between the gas cylinder 1 and the gas flowmeter 3; the first hydraulic gauge 5 is arranged on a pressure detection port 6 of the air heater 4; what is needed isThe second hydraulic gauge 21 is arranged on a pipeline connecting the third stop valve 23 and the second three-way valve 20; the first three-way valve 7 is arranged on a pipeline between the first stop valve 7 and the reaction kettle air inlet 9; the second three-way valve 19 is arranged on a pipeline connecting the second stop valve 19 and the second hydraulic gauge 21; the third three-way valve 22 is arranged on a pipeline connecting the second stop valve 19 and the second hydraulic gauge 21; the first stop valve 7 is arranged on a pipeline connecting the air heater 4 and the first three-way valve 8; the second stop valve 19 is disposed on a connection pipe between the wet gas flowmeter 17 and the second three-way valve 20; the third stop valve 23 is disposed between the second hydraulic gauge 21 and the CH4The connecting conduit between the pressure relief valves 24.
The heat injection-displacement combined exploitation method of the natural gas hydrate comprises the following steps:
(1) adding 110.5g of quartz sand and 50.3g of ice powder into a reaction kettle 11, vacuumizing, and opening CH4A pressure reducing valve 24, a third stop valve 23 and a second stop valve 19, and CH is filled in the reaction kettle 114Until the pressure became 12.4MPa, CH charged in the reaction vessel 11 was measured by a wet mass flow meter 174Measuring, recording CH filled in the reaction vessel 114Has a gas volume of V1Opening the constant-temperature water tank 13 when the volume is 180.2ml, and setting the temperature of the constant-temperature water tank 13 to be-6 ℃;
(2) when the pressure in the reaction kettle reaches 5MPa, closing CH4A pressure reducing valve 24, a first stop valve 7, a second stop valve 19 and a third stop valve 23, and filling the replacement gas into the air heater 4, wherein the temperature of the air heater 4 is set to be 120 ℃;
(3) when the readings of the pressure sensor 18 and the temperature sensor 10 are not changed any more, namely after the hydrate is generated, the second stop valve 19 is opened, and the CH for reaction in the reaction kettle 11 is4Gas is discharged and the discharged CH is measured by a wet mass flow meter 174Volume, recording volume V2165.1ml, recording the pressure indication of the air heater 4 reaching the set temperature as 12 MPa;
(4) the second stop valve 19 is closed, the first stop valve 7 is opened, and the replacement gas in the air heater 4 is filled into the reaction vessel 11 through the gas inlet and the first three-way valve 7, and when the replacement gas is filledReplacement gas (CO) into the reaction vessel 112:N20.87) and when the pressure reaches 12.3MPa, closing the first stop valve 7, and simultaneously adjusting the temperature of the constant-temperature water tank 13 to 1.0 ℃;
(5) the reaction time was 153h and the gas composition was measured by gas chromatography every 6 hours until the CH was determined4The content of (A) is constant;
(6) when CH is present4When the content is not changed any more, the temperature of the constant temperature water tank 13 is raised to completely decompose the hydrate after the reaction, the second stop valve 19 is opened, and the volume V of the replacement gas generated after the decomposition of the residual hydrate is measured by the wet mass flow meter 17369.2ml and the composition of the decomposed gas was measured by gas chromatography to determine CH in the displaced gas4The gas accounts for yCH4Is 0.056 and passes the constant CH measured in step 64Comparing the contents to obtain final natural gas hydrate production rate data;
(7) the data are collated and calculated, and the final mining rate eta in the process is 74.2%:
example 2
The apparatus was the same as in example 1.
The device and the method are used for carrying out hydrate generation and replacement gas replacement exploitation experiments, and the experimental process is as follows:
(1) adding 110.5g of quartz sand and 50.3g of ice powder into a reaction kettle 11, vacuumizing, and opening CH4A pressure reducing valve 24, a third stop valve 23 and a second stop valve 19, and CH is filled in the reaction kettle 114Until the pressure became 12.8MPa, CH filled in the reaction vessel 11 was measured by a wet mass flow meter 174Measuring, recording CH filled in the reaction vessel 114Has a gas volume of V1The volume is 181.7ml, the constant temperature water tank 13 is opened, and the temperature of the constant temperature water tank 13 is set to be-6 ℃;
(2) when the pressure in the reaction kettle reaches 25MPa, closing CH4A pressure reducing valve 24, a first cut-off valve 7, a second cut-off valve 19, and a third cut-off valve 23;
(3) when the readings of the pressure sensor 18 and the temperature sensor 10 are not changed any more, namely after the hydrate is generated, the second stop valve 19 is opened, and the CH for reaction in the reaction kettle 11 is4Gas is discharged and the discharged CH is measured by a wet mass flow meter 174Volume, recording volume V2166.4 ml;
(4) the second cut-off valve 19 is closed, the first cut-off valve 7 is opened, and the replacement gas in the air heater 4 is introduced into the reaction vessel 11 through the gas inlet and the first three-way valve 7, and then the replacement gas (CO) introduced into the reaction vessel 11 is introduced2:N20.87), closing the first stop valve 7 and simultaneously adjusting the temperature of the constant-temperature water tank 13 to 1.0 ℃ after the pressure reaches 12 MPa;
(5) the reaction time was 165h and the gas composition was measured by gas chromatography every 6 hours until the CH was measured4The content of (A) is constant;
(6) when CH is present4When the content is not changed any more, the temperature of the constant temperature water tank 13 is raised to completely decompose the hydrate after the reaction, the second stop valve 19 is opened, and the volume V of the replacement gas generated after the decomposition of the residual hydrate is measured by the wet mass flow meter 17387.2ml and the composition of the gas after decomposition was measured by gas chromatography to determine CH in the displaced gas4The gas accounts for yCH4Is 0.056 and passes the constant CH measured in step 64Comparing the contents to obtain final natural gas hydrate production rate data;
(7) the data are collated and calculated, and the final mining rate eta in the process is 68.1%:
Claims (22)
1. a natural gas hydrate heat injection-displacement combined simulated production device, wherein the device comprises: gas replacement cylinder (1), CH4The system comprises a gas cylinder (25), a first gas flowmeter (3), a second gas flowmeter (17), a heater (4), a temperature control device (13), a reaction kettle (11), a data acquisition instrument (15) and a computer (16); inverse directionThe reactor (11) is arranged in the temperature control device (13) to control the temperature in the reaction vessel through the temperature control device, the replacement gas cylinder (1), the first gas flowmeter (3), the heater (4) and the reactor (11) are sequentially connected through a first pipeline (26), and CH4The gas cylinder (25), the second gas flowmeter (17) and the reaction kettle (11) are sequentially connected through a second pipeline (27), and the data acquisition instrument (15) is electrically connected with the reaction kettle (11) and the computer (16) respectively.
2. The simulated mining device of claim 1, wherein the reaction kettle (11) comprises a kettle body (29), a kettle cover (28) arranged at the top of the kettle body (29), a gas inlet and outlet (9) arranged on the kettle cover (28), and a sand outlet (14) arranged at the bottom of the kettle body (29); the kettle cover (28) is provided with a pressure detection interface (26) and a temperature detection interface (27) which are connected to the inner cavity of the kettle body (29), and the coil pipe (12) extends into the inner cavity of the kettle body (29) through the gas inlet and outlet (9).
3. The simulated mining apparatus as claimed in claim 2, wherein the reaction vessel (11) further comprises a support (30) provided at the bottom of the vessel body (29) for supporting the vessel body (29).
4. The simulated mining device as claimed in claim 2, wherein the reaction vessel (11) further comprises a pressure sensor (18) electrically connected with the pressure detection interface (26) and a temperature sensor (10) arranged at the temperature detection interface (27); the pressure sensor (18) and the temperature sensor (10) are respectively and electrically connected with the data acquisition instrument (15).
5. The simulated mining apparatus of claim 2 wherein the height of the coiled tubing (12) is 1/4-1/2 of the height of the reactor cavity; the diameter is 0.25-0.75 of the diameter of the inner cavity of the reaction kettle; the spiral diameter of the coil is 0.25-0.75 times of the inner diameter of the reaction kettle.
6. The simulated mining device of claim 2, wherein the coiled tubing (12) is provided with air holes (121), and the distance between any two adjacent air holes is 0.2-0.8 times the outer diameter of the coiled tubing.
7. A simulated mining apparatus as claimed in any of claims 1 to 6, wherein the apparatus further comprises a replacement gas pressure reducing valve (2) provided in the conduit between the replacement gas cylinder (1) and the first gas flow meter (3), and a replacement gas pressure reducing valve provided in the CH conduit4CH on the line between the gas cylinder (25) and the second gas flow meter (17)4A pressure reducing valve (24).
8. A simulated mining device as claimed in claim 7, wherein the device further comprises a second three-way valve (20), a third three-way valve (22), a first shut-off valve (7), a second shut-off valve (19), a third shut-off valve (23); a second stop valve (19), a second three-way valve (20), a third three-way valve (22) and a third stop valve (23) are arranged in the second gas flow meter (17) and the CH in this order from the second gas flow meter (17)4The first stop valve (7) is arranged on the pipeline between the heater (4) and the reaction kettle (11).
9. The simulated mining apparatus of claim 8, wherein the apparatus further comprises a first hydraulic pressure gauge (5) and a second hydraulic pressure gauge (21); the first hydraulic gauge (5) is arranged on the heater (4), and the second hydraulic gauge (21) is arranged on the third three-way valve (22).
10. The simulated mining device as claimed in claim 8, wherein the device further comprises a first three-way valve (8), the first three-way valve (8) being arranged on the line between the first shut-off valve (7) and the reaction vessel (11), the second line (27) being connected to the reaction vessel (11) via the first three-way valve (8).
11. A natural gas hydrate heat injection-displacement combined simulated exploitation method comprises the steps of introducing methane into a reaction kettle filled with ice powder and quartz sand to generate a hydrate; after the hydrate is formed, the displacement reaction is carried out by introducing heated displacement gas.
12. The method of claim 11, wherein the mass ratio of ice powder to quartz sand is 0.5: 1-1: 0.5.
13. the method as claimed in claim 11, wherein the method comprises introducing methane into the reaction kettle containing the ice powder and the quartz sand, and controlling the pressure in the reaction kettle to be more than 3MPa until the methane is not consumed any more.
14. A method according to any one of claims 11 to 13, wherein the method comprises using the apparatus of claim 8 or 10, comprising the steps of:
(1) adding quartz sand and ice powder into a reaction kettle (11), vacuumizing, and opening CH4A pressure reducing valve (24), a third stop valve (23) and a second stop valve (19), and CH is filled in the reaction kettle (11)4And a second gas flowmeter (17) is used for measuring CH filled in the reaction kettle4Measuring, recording CH filled in the reaction kettle4Has a gas volume of V1Opening the temperature control device (13) and observing the generated hydrate;
(2) when the pressure in the reaction kettle reaches 5-25 MPa, closing CH4A pressure reducing valve (24), a first cut-off valve (7), a second cut-off valve (19), and a third cut-off valve (23) for charging the replacement gas into the heater (4);
(3) when the pressure and the temperature in the reaction kettle (11) are not changed any more, a second stop valve (19) is opened, and the unreacted CH in the reaction kettle (11) is treated4Gas exhaust and wet mass flow meter measurement of exhausted CH4Volume, recording volume V2Recording the pressure indication when the heater (4) reaches the set temperature;
(4) closing the second stop valve (19), opening the first stop valve (7), filling the replacement gas in the heater (4) into the reaction kettle (11), closing the first stop valve (7), and simultaneously adjusting the temperature of the temperature control device (13) to be the set temperature;
(5) the reaction time is 70 h-200 h, and the gas component in the reaction kettle (11) is measured every 2-6 hours until the measured CH4The content of (A) is constant;
(6) when CH is present4When the content no longer changes, literThe temperature of the temperature control device (13) is increased to completely decompose the hydrate after reaction, the second stop valve (19) is opened, and the volume V of the replacement gas generated after the decomposition of the residual hydrate is measured by a wet mass flow meter3And measuring the composition of the decomposed gas to determine CH in the displaced gas4The proportion of gas is yCH4And by constant CH determined in step (6)4Comparing the contents to obtain final natural gas hydrate production rate data;
(7) data are sorted and calculated, and the final mining rate eta in the process is:
15. the method as claimed in claim 14, wherein the step (1) comprises charging the reaction vessel (11) (11) with CH4Until the pressure in the reaction kettles (11) and (11) is 6MPa to 12 MPa.
16. The method according to claim 14, wherein step (1) comprises setting the temperature of the temperature control device (13) to-9 ℃ -2 ℃ after the temperature control device (13) is turned on.
17. The method according to claim 14, wherein the temperature of the heater (4) in step (2) is set to 105-300 ℃.
18. The method according to claim 14, wherein the first shut-off valve (7) is closed after the pressure of the replacement gas charged into the reaction vessel (11) in step (4) reaches 10MPa to 16 MPa.
19. The method according to claim 14, wherein the temperature of the temperature control device (13) is adjusted to 1 ℃ to 4 ℃ in step (4).
20. The method according to claim 14, wherein step (6) is carried out by raising the temperature of the temperature control device (13) to 25-50 ℃.
21. The method of any one of claims 11 to 20, wherein the displacement gas is a gas comprising CO2Based on the total volume of the displacement gas as 100%, CO2The content of the volume percent is 15-100%.
22. The method of claim 21, wherein the displacement gas is N2/CO2Mixed gases or CO2When the replacement gas is N2/CO2When gas is mixed, N2And CO2Is 1: (0.05-100).
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