CN117949615A - Experimental device and experimental method for separating components of flue gas in aquifer - Google Patents
Experimental device and experimental method for separating components of flue gas in aquifer Download PDFInfo
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- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 title claims abstract description 155
- 238000002474 experimental method Methods 0.000 title claims abstract description 24
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims abstract description 298
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims abstract description 281
- 239000007789 gas Substances 0.000 claims abstract description 171
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Abstract
The invention discloses an experimental device and an experimental method for separating components of flue gas in an aquifer, wherein the experimental device for separating components of the flue gas in the aquifer is characterized by comprising a constant pressure constant speed pump, a first six-way valve, a second six-way valve, a third six-way valve, a nitrogen intermediate container, a carbon dioxide intermediate container, a nitrogen flow controller, a carbon dioxide flow controller, a simulated flue gas intermediate container, an incubator, a core holder, a confining pressure back pressure pump, a back pressure valve, a gas-liquid separator, a produced water meter, a one-way valve, a gas flowmeter, a produced gas storage tank, a first two-way valve and a second two-way valve; the constant-pressure constant-speed pump is connected with the first end of the first six-way valve, the second end of the first six-way valve is connected with one end of the nitrogen intermediate container, and the other end of the nitrogen intermediate container is sequentially connected with the nitrogen flow controller and one end of the first two-way valve.
Description
Technical Field
The invention relates to the technical field of oil and gas field exploitation, in particular to an experimental device and an experimental method for separating components of flue gas in an aquifer.
Background
Global climate change caused by greenhouse gas emissions is one of the most serious environmental problems facing humans in the 21 st century. Carbon dioxide is used as the main greenhouse gas, the annual emission of the carbon dioxide is about 340 hundred million tons, and the carbon dioxide accounts for about 80 percent of the total amount of the greenhouse gas emitted by human activities. The emission of flue gases is one of the sources of increasing greenhouse effect. Flue gas refers to environmental-polluting gaseous substances produced when fossil fuels such as coal and petroleum are burned, and these substances are usually discharged from a flue or a chimney. The flue gas contains 15-20% of carbon dioxide and 75-80% of nitrogen, and has the characteristics of low partial pressure of carbon dioxide and complex gas components (small amount of CO, O 2、SO2、NOX and the like). And thus the separation of carbon dioxide from flue gas is more difficult. Worldwide, large emission sources of flue gases are mainly focused on power plants, cement manufacturing enterprises, the steel industry, and the oil and gas processing industry.
Thermal power plants using fossil fuel as a main energy source are the largest concentrated emission sources of flue gas, and carbon dioxide in the flue gas of the power plant accounts for 37.5% of the total carbon emission. For our country, 75% of the electricity is still produced by coal-fired power plants, so the separation and sequestration of flue gas generated in industrial processes at low cost and high efficiency is a current urgent need. However, the flue gas component contains 75% -80% of nitrogen, which occupies most of the flue gas, and direct storage without separation occupies a large amount of underground storage space, so that the storage efficiency is low.
The main technical means of flue gas separation at present are absorption, adsorption, cryogenic distillation and membrane separation. Absorption methods are mainly classified into two types, physical absorption and chemical absorption. The physical absorption utilizes physical conditions such as temperature, pressure and the like, and the solubility of each component in the gas mixture is controlled, so that the separation of different components is realized, and the method is only applicable to the condition of higher partial pressure of carbon dioxide; the chemical absorption method is to make the flue gas and the absorption liquid react in the absorption tower, and the main problems existing at present are large energy consumption, large investment and low efficiency. The adsorption method is a method for selectively adsorbing a certain gas in a gas mixture on the surface of a solid adsorbent, and can only be carried out at low temperature and high pressure, is suitable for flue gas with high partial pressure of carbon dioxide, and has low separation efficiency. The cryogenic distillation method is a physical method for separating carbon dioxide by cryogenic condensation, and has problems of auxiliary equipment and energy consumption but low separation efficiency. The membrane separation technology uses the pressure difference between the air inlet side and the permeation side of the two sides of the membrane as driving force, and achieves the separation purpose through different dissolution and diffusion properties of different components in the gas mixture in the membrane, but the waste membrane treatment after the membrane separation can pollute the environment, and the purity of the obtained gas is lower. At the same time, each of the above-listed separation methods is performed on the ground and requires a special set of separation system equipment, increasing equipment investment and system complexity.
The carbon dioxide is captured and then is subjected to sealing treatment, and a currently feasible and large-scale sealing mode is geological sealing. Geological sequestration means the sequestration of carbon dioxide in different subsurface reservoir spaces, specific reservoir spaces including abandoned hydrocarbon reservoirs, salty water layers, coal layers, hydrate reservoirs, and the like. The main mechanism of sealing includes four aspects: the density difference of gas and water generates gravity difference and the structure of cover layer shielding is sealed and stored; dissolving and sealing carbon dioxide in stratum water; residual gas sealing exists at the pore throat of the rock under the actions of capillary force and particle surface adsorption; mineral sequestration of the geochemical reactions that occur between carbon dioxide, formation water, and rock minerals. The geological sequestration mechanism of the patent for the carbon dioxide is the comprehensive application of the four mechanisms in the aquifer.
The traditional flue gas component separation and carbon dioxide burying process are separated, a flue gas component separation equipment system and a carbon dioxide underground burying equipment system are needed, ground facilities are complex, investment is large, energy consumption is high, and separation and burying efficiency is low.
The foregoing is provided merely for the purpose of facilitating understanding of the technical solutions of the present invention and is not intended to represent an admission that the foregoing is prior art.
Disclosure of Invention
The invention mainly aims to provide an experimental device and an experimental method for separating components of flue gas in an aquifer, and aims to solve or partially solve the problems.
In order to achieve the aim, the invention provides an experimental device for separating components of flue gas in an aquifer, which comprises a constant pressure constant speed pump, a first six-way valve, a second six-way valve, a third six-way valve, a nitrogen intermediate container, a carbon dioxide intermediate container, a nitrogen flow controller, a carbon dioxide flow controller, a simulated flue gas intermediate container, a constant temperature box, a core holder, a confining pressure return pump, a return pressure valve, a gas-liquid separator, a produced water meter, a one-way valve, a gas flowmeter, a produced gas storage tank, a first two-way valve and a second two-way valve; the constant-pressure constant-speed pump is connected with the first end of the first six-way valve, the second end of the first six-way valve is connected with one end of the nitrogen intermediate container, and the other end of the nitrogen intermediate container is sequentially connected with the nitrogen flow controller and one end of the first two-way valve; the third end of the first six-way valve is connected with one end of the carbon dioxide intermediate container, the other end of the carbon dioxide intermediate container is sequentially connected with the carbon dioxide flow controller and one end of the second bi-directional valve, and the other end of the first bi-directional valve is connected with the other end of the second bi-directional valve and then is connected with the first end of the second six-way valve; the lower end of the simulated flue gas intermediate container is connected with the fourth end of the first six-way valve, and the upper end of the simulated flue gas intermediate container is connected with the second end of the second six-way valve; the third end of the second six-way valve is connected with the first end of the core holder, and the core holder is arranged in the incubator; the middle part of the core holder is connected with the first end of the third six-way valve, the second end of the third six-way valve is connected with the confining pressure back pressure pump, the third end of the third six-way valve is connected with the first end of the back pressure valve, the second end of the core holder is connected with the second end of the back pressure valve, and the third end of the back pressure valve is connected to the first end of the gas-liquid separator; the second end of the gas-liquid separator is sequentially connected with a one-way valve, a gas flowmeter and a produced gas storage tank; and the third end of the carbon dioxide intermediate container is connected with a produced water meter.
Preferably, in the experimental method of the separation of the components of the flue gas in the aquifer, an experimental method of the above experimental apparatus is employed, the experimental method comprising:
Preparing simulated flue gas through a nitrogen intermediate container and a carbon dioxide intermediate container, wherein the simulated flue gas enters the simulated flue gas intermediate container, and nitrogen and carbon dioxide in the simulated flue gas are in a preset proportion;
Placing the rock core after saturation of stratum water into a rock core holder, and then placing the rock core holder into an incubator so as to enable two ends of the rock core holder to be closed and constant in temperature, thereby simulating the temperature condition of an underground aquifer;
Applying P IN +6MPa preset confining pressure to the core holder through a confining pressure back pressure pump, and applying P OUT preset back pressure to a back pressure valve at the tail end of the core holder through the confining pressure back pressure pump so as to build a pressure environment similar to or the same as an underground aquifer in the core holder;
Opening a constant-pressure constant-speed pump, a first six-way valve, a switch of a simulated flue gas intermediate container and a valve switch connected with a core holder, injecting deionized water into the simulated flue gas intermediate container in a constant-pressure mode, pushing a piston in the simulated flue gas intermediate container to move upwards to inject simulated flue gas into the core holder at P IN pressure, detecting pressure changes at two ends of injection and production of the core holder in real time, and realizing constant injection and production pressure difference at two ends of the core holder through communication with the constant-pressure constant-speed pump;
Injecting flue gas to drive stratum water in the core to move, when the pressure at the tail end of the core holder exceeds back pressure P OUT, opening a back pressure valve, producing stratum water and flue gas from the tail end of the core holder, carrying out gas-liquid separation on the produced gas-liquid mixture through a gas-liquid separator, and metering and storing liquid through a produced water metering instrument; the separated gas passes through a one-way valve, the instantaneous and accumulated flow is measured by a gas flowmeter, and the produced gas component is monitored on line in real time, so that the produced gas component and the change of the produced gas component along with time are clear.
Preferably, in the experimental method for separating the components of the flue gas in the aquifer, the experimental effect of the plane of the aquifer and the longitudinal factors on the separation of the components of the flue gas is realized by increasing the number of core holders and by different connection modes.
Preferably, in the experimental method of the separation of the components of the flue gas in the aquifer, the number of core holders is a plurality, wherein,
The plurality of core holders are arranged in series, the total length of the core is increased, and the total length of the plurality of core holders corresponds to the actual injection and production well distance in the field, so that experiments are carried out on the influence of the plane distance of the aquifer on the separation of the components of the flue gas; or alternatively
The core holders are arranged in parallel to simulate the longitudinal factors of the aquifer so as to determine the influence rule of the longitudinal factors of the aquifer of the multi-layer system on the separation of the components of the flue gas.
In order to achieve the above object, the present invention provides an integrated method for separating nitrogen from carbon dioxide in flue gas by using an underground aquifer, comprising:
Well pattern deployment is carried out on a preset aquifer, a plurality of injection wells and extraction wells are distributed on the aquifer, the injection wells and the extraction wells are distributed at intervals, the injection wells and the extraction wells are distributed along a first direction to form one-dimensional linear flow or quasi-one-dimensional linear flow, wherein the permeability of the aquifer is greater than 50mD, the porosity is greater than 0.15, and the thickness of the aquifer is greater than 10m;
Controlling the injection of flue gas from an injection well to reach a preset duration, injecting liquid and keeping the bottom hole pressure unchanged;
when the production well starts to produce gas, controlling the bottom hole flow pressure of the production well to be kept at a first preset pressure;
When the mole fraction of the nitrogen produced by the production well is lower than a first preset value, closing the production well and simultaneously closing the injection well;
The first preset value is determined according to experimental data obtained by the experimental method.
Preferably, in the integrated method for separating nitrogen from carbon dioxide in flue gas by using an underground aquifer, the first preset value is 0.95.
Preferably, in the integrated method for separating nitrogen from flue gas and burying carbon dioxide by using underground aquifers, after the step of injecting liquid and maintaining bottom hole pressure unchanged after the step of injecting flue gas from an injection well for a preset period of time, the method further comprises:
Based on the experimental method of the component separation of the flue gas in the aquifer, the nitrogen separation rate under different temperatures and pressures is obtained by changing the temperature and the pressure of the aquifer;
Constructing a nitrogen separation efficiency plate according to nitrogen separation rates at different temperatures and pressures;
determining turning points of nitrogen separation efficiency change according to the constructed nitrogen separation efficiency plate;
And determining the first aquifer pressure, the first aquifer temperature and the first separation efficiency in the optimal state according to the determined turning points.
Preferably, in the integrated method for separating nitrogen from flue gas and burying carbon dioxide by using an underground aquifer, well pattern deployment is performed in a preset aquifer, a plurality of injection wells and extraction wells are arranged in the aquifer, the injection wells and the extraction wells are arranged at intervals, and before the step of arranging the plurality of injection wells and the extraction wells along a first direction to form a one-dimensional linear flow or a quasi-one-dimensional linear flow, the integrated method further comprises:
optimizing the buried depth of the aquifer, wherein the optimizing method comprises the following steps:
Calculating the corresponding specific volume of the gas according to the temperature and pressure conditions;
；
Wherein P is the gas pressure;
t is the gas temperature;
V is the specific volume of the gas;
r is the gas constant, r= 8.314 kJ/(kmol·k);
a (T), b are critical temperature and pressure functions;
；
；
；
；
Alpha and m are both calculation coefficients;
p c is the gas critical pressure;
T c is the critical temperature of the gas;
omega is the gas eccentricity factor;
and determining the buried depth of the aquifer according to the specific volume of the gas.
The invention also provides a prediction method of nitrogen separation rate in flue gas component separation by using the underground aquifer, the method is used for flue gas component separation by using the underground aquifer, and the prediction method comprises the following steps:
And searching the corresponding nitrogen separation rate according to the temperature and pressure of the current aquifer and a pre-established nitrogen separation efficiency chart.
The invention has at least the following beneficial effects:
The invention provides an experimental device for separating components of flue gas in an aquifer, wherein a constant pressure constant speed pump is connected with a first end of a first six-way valve, a second end of the first six-way valve is connected with one end of a nitrogen intermediate container, and the other end of the nitrogen intermediate container is sequentially connected with a nitrogen flow controller and one end of a first two-way valve; the third end of the first six-way valve is connected with one end of the carbon dioxide intermediate container, the other end of the carbon dioxide intermediate container is sequentially connected with the carbon dioxide flow controller and one end of the second bi-directional valve, and the other end of the first bi-directional valve is connected with the other end of the second bi-directional valve and then is connected with the first end of the second six-way valve; the lower end of the simulated flue gas intermediate container is connected with the fourth end of the first six-way valve, and the upper end of the simulated flue gas intermediate container is connected with the second end of the second six-way valve; the third end of the second six-way valve is connected with the first end of the core holder, and the core holder is arranged in the incubator; the middle part of the core holder is connected with the first end of the third six-way valve, the second end of the third six-way valve is connected with the confining pressure back pressure pump, the third end of the third six-way valve is connected with the first end of the back pressure valve, the second end of the core holder is connected with the second end of the back pressure valve, and the third end of the back pressure valve is connected to the first end of the gas-liquid separator; the second end of the gas-liquid separator is sequentially connected with a one-way valve, a gas flowmeter and a produced gas storage tank; the third end of the carbon dioxide intermediate container is connected with a produced water meter, so that flue gas separation can be realized in a simulation mode.
Drawings
FIG. 1 is a schematic diagram of an embodiment of an experimental set-up for the separation of components of flue gas in an aquifer provided by the present invention;
FIG. 2 is a graph showing the change of the gas production speed with the production time;
FIG. 3 is a graph showing the change of the mole fraction of the gas with the production time;
FIG. 4 is a graph showing the change of the molar flow rate of the gas with the production time;
FIG. 5 is a graph showing the change rule of the saturation of the gas with the injection and production well spacing;
FIG. 6 is a graph of total mole fraction of each component of the gas according to the present invention as a function of injection and production well spacing;
FIG. 7 is a graph showing the change rule of the mole fraction of the gas component in the water phase along with the injection and production well spacing;
FIG. 8 is a graph showing the change rule of the mole fraction of the gas component in the gas phase according to the injection well spacing;
FIG. 9 is a graph of gas-water permeation according to the present invention;
FIG. 10 is a graph showing the variation rule of seepage velocity with the injection and production well spacing according to the invention;
FIG. 11 is a graph of nitrogen separation efficiency under the combined influence of aquifer pressure and temperature in accordance with the present invention;
FIG. 12 is a graph showing the variation of water and gas production rate with flue gas injection volume;
FIG. 13 is a graph of the variation of produced gas composition with flue gas injection volume;
FIG. 14 is a graph showing the variation of nitrogen density with the depth of burial of an aquifer according to an embodiment;
FIG. 15 is a graph showing a variation law of carbon dioxide density with depth of burial of an aquifer.
1-Constant pressure constant speed pump, 21-first six-way valve, 22-second six-way valve, 23-third six-way valve, 31-nitrogen intermediate container, 32-carbon dioxide intermediate container, 41-nitrogen flow controller, 42-carbon dioxide flow controller, 43-simulated flue gas intermediate container, 51-thermostated container, 52-core holder, 61-confining pressure back pressure pump, 62-back pressure valve, 71-gas-liquid separator, 72-multicomponent gas online analyzer, 73-check valve, 74-gas flowmeter, 75-produced gas storage tank, 76-first two-way valve, 77-second two-way valve, 78-produced water gauge.
The achievement of the objects, functional features and advantages of the present invention will be further described with reference to the accompanying drawings, in conjunction with the embodiments.
Detailed Description
In the embodiment of the invention, the term "and/or" describes the association relation of the association objects, which means that three relations can exist, for example, a and/or B can be expressed as follows: a exists alone, A and B exist together, and B exists alone. The character "/" generally indicates that the context-dependent object is an "or" relationship.
It should be noted that the terms "first," "second," and the like in the description and the claims of the present invention and the above figures are used for distinguishing between similar objects and not necessarily for describing a particular sequential or chronological order.
The term "plurality" in embodiments of the present invention means two or more, and other adjectives are similar.
For the purpose of making the objects, technical solutions and advantages of the embodiments of the present invention more apparent, the embodiments of the present invention will be described in detail below with reference to the accompanying drawings. However, it will be understood by those of ordinary skill in the art that in various embodiments of the present invention, numerous specific details are set forth in order to provide a thorough understanding of the present invention. The claimed invention may be practiced without these specific details and with various changes and modifications based on the following embodiments. The following embodiments are divided for convenience of description, and should not be construed as limiting the specific implementation of the present invention, and the embodiments can be mutually combined and referred to without contradiction.
Referring to fig. 1, the experimental apparatus for the separation of components of the flue gas in the aquifer comprises a constant pressure constant speed pump 1, a first six-way valve 21, a second six-way valve 22, a third six-way valve 23, a nitrogen intermediate container 31, a carbon dioxide intermediate container 32, a nitrogen flow controller 41, a carbon dioxide flow controller 42, a simulated flue gas intermediate container 43, a constant temperature box 51, a core holder 52, a confining pressure return pump 61, a back pressure valve 62, a gas-liquid separator 71, a produced water meter 78, a one-way valve 73, a gas flow meter 74, a produced gas storage tank 75, a first two-way valve 76, and a second two-way valve 77;
The constant-pressure constant-speed pump 1 is connected with a first end of the first six-way valve, a second end of the first six-way valve is connected with one end of the nitrogen intermediate container 31, and the other end of the nitrogen intermediate container 31 is sequentially connected with the nitrogen flow controller 41 and one end of the first two-way valve 76; the third end of the first six-way valve is connected with one end of the carbon dioxide intermediate container 32, the other end of the carbon dioxide intermediate container 32 is sequentially connected with one end of the carbon dioxide flow controller 42 and one end of the second bi-directional valve 77, and the other end of the first bi-directional valve 76 is connected with the other end of the second bi-directional valve 77 and then is connected with the first end of the second six-way valve 22; the lower end of the simulated flue gas intermediate vessel 43 is connected with the fourth end of the first six-way valve 21, and the upper end is connected with the second end of the second six-way valve 22; a third end of the second six-way valve 22 is connected with a first end of the core holder 52, and the core holder 52 is arranged in the incubator 51; the middle part of the core holder 52 is connected with a first end of the third six-way valve 23, a second end of the third six-way valve 23 is connected with the confining pressure return pump 61, a third end of the third six-way valve 23 is connected with a first end of a back pressure valve 62, a second end of the core holder 52 is connected with a second end of the back pressure valve 62, and a third end of the back pressure valve 62 is connected with a first end of the gas-liquid separator 71; the second end of the gas-liquid separator 71 is sequentially connected with a one-way valve 73, a gas flowmeter 74 and a produced gas storage tank 75; the third end of the carbon dioxide intermediate vessel 32 is connected to a produced water meter 78.
Based on example 1, the invention also provides an experimental method for the separation of components of flue gas in an aquifer, the experimental method comprising:
Preparing simulated flue gas through the nitrogen intermediate container 31 and the carbon dioxide intermediate container 32, wherein the simulated flue gas enters the simulated flue gas intermediate container 43, and the nitrogen and the carbon dioxide in the simulated flue gas are in a preset proportion;
Placing the core after saturation of stratum water into a core holder 52, and then placing the core holder 52 into a constant temperature box 51 so as to enable two ends of the core holder 52 to be closed and constant temperature, thereby simulating the temperature condition of an underground aquifer;
Applying P IN +6MPa preset confining pressure to the core holder 52 through the confining pressure back pressure pump 61, and applying P OUT preset back pressure to the back pressure valve 62 at the tail end of the core holder 52 through the confining pressure back pressure pump 61 so as to build a pressure environment similar to or the same as an underground aquifer in the core holder 52;
Opening a constant-pressure constant-speed pump 1, a switch of a first six-way valve 21 and a simulated flue gas intermediate container 43, and a valve switch for connecting the simulated flue gas intermediate container 43 and a core holder 52, injecting deionized water into the simulated flue gas intermediate container 43 in a constant-pressure mode, pushing a piston in the simulated flue gas intermediate container 43 to move upwards to inject simulated flue gas into the core holder 52 at P IN pressure, detecting pressure changes at two injection and production ends of the core holder 52 in real time, and realizing constant injection and production pressure difference at two ends of the core holder 52 through communication with the constant-pressure constant-speed pump 1;
Injecting flue gas to drive stratum water in the core to move, when the pressure at the tail end of the core holder 52 exceeds the back pressure P OUT, opening a back pressure valve 62, producing stratum water and flue gas from the tail end of the core holder 52, and measuring and storing liquid by a produced water meter after the produced gas-liquid mixture is subjected to gas-liquid separation by a gas-liquid separator 71; the separated gas passes through a one-way valve 73, and the instantaneous and cumulative flow rates are measured by a gas flow meter 74, and the produced gas components are monitored on line in real time, so that the produced gas components and the changes thereof with time are clarified.
By increasing the number of core holders 52 and by different connection means, experiments were carried out on the influence of the aquifer plane and longitudinal factors on the separation of the flue gas components. The number of the core holders 52 is multiple, wherein the core holders 52 are arranged in series, the total length of the core is increased, and the total length of the core holders 52 corresponds to the actual injection and production well spacing in site, so that experiments are carried out on the influence of the plane distance of the aquifer on the separation of the flue gas components; the plurality of core holders 52 are arranged in parallel to simulate the longitudinal factors of the aquifer so as to define the influence rule of the longitudinal factors of the aquifer of the multi-layer system on the separation of the components of the flue gas.
For convenience of explanation, specific examples are described below.
(1) Simulated flue gas production
The experimental set-up for the separation of components of the flue gas in an aquifer provided in example 1 was subjected to an air tightness test. Before the experiment starts, nitrogen with the purity of 4N is respectively filled into the nitrogen intermediate container 31 of the device to the set pressure P IN; the carbon dioxide intermediate container 32 was filled with carbon dioxide having a purity of 4N to the set pressure P IN.
According to the experimentally set flue gas volume injection rate Q IN, the volume flows Q N2 and Q CO2 under standard conditions were calculated in a ratio of nitrogen to carbon dioxide mole fraction ratio of 7:3, and the flow rate of the nitrogen flow controller 41 was set to Q N2, and the flow rate of the carbon dioxide flow controller 42 was set to Q CO2.
The constant pressure constant speed pump 1 is started, and the first six-way valve 21, the switch connecting the nitrogen intermediate tank 31 and the carbon dioxide intermediate tank 32, and the first bi-directional valve 76 and the second bi-directional valve 77 are opened. The constant pressure and constant speed pump 1 simultaneously injects deionized water into the nitrogen intermediate container 31 and the carbon dioxide intermediate container 32 in a constant speed mode, and pushes the piston in the intermediate container to move so as to indirectly push the nitrogen and the carbon dioxide to flow into the simulated flue gas intermediate container 43 according to a set proportion through the flow controller.
The pressure sensor is used to monitor the pressure change in the simulated flue gas intermediate vessel 43 in real time during the injection process. After the pressure in the simulated flue gas intermediate vessel 43 reaches the set pressure P IN, the first bi-directional valve 76, the second bi-directional valve 77, and the constant pressure constant speed pump 1 are closed, stopping the injection. Thus, a simulated flue gas having a nitrogen to carbon dioxide mole fraction ratio of 7:3 and a pressure of P IN was obtained.
For simulated flue gas production at any mole fraction ratio of nitrogen to carbon dioxide, this method need only be used to vary the flow rate of the nitrogen flow controller 41 and the flow rate of the carbon dioxide flow controller 42 in the same proportion at the same time, and is not repeated here.
(2) Experimental core selection and saturated stratum water
When the experimental core is selected, the core obtained by drilling and coring the target buried aquifer is preferentially selected, and a plurality of cores are connected in series so as to fully reflect the difference of experimental results; if the core is not actually coring, the artificial core can be manufactured to replace according to the physical characteristics of porosity, permeability and the like of the target buried aquifer, and the core length is preferably 20cm long.
According to the mineral composition of the stratum water of the target buried aquifer, the simulated stratum water with the same components and proportions is prepared. The core is put into a constant temperature box 51 and is set at a constant temperature of 60 ℃ and dried for 12 hours. And then placing the rock core into an intermediate container, vacuumizing for 8 hours, injecting the prepared simulated formation water into a vacuum container filled with the rock core, and continuously injecting the simulated formation water into the intermediate container by using a constant-pressure constant-speed pump 1 after the rock core is completely immersed until the pressure in the container reaches 20.0MPa, and saturating for 8 hours under pressure to finish the process of saturating the rock core with the formation water.
(3) Flue gas displacement formation water experiment
The core after saturation of formation water is put into the core holder 52, after which the core holder 52 is put into the incubator 51 and the temperature of the incubator 51 is set to T. The two ends of the core holder 52 were closed and kept at constant temperature for 2 hours, thereby simulating the actual underground aquifer temperature conditions. The core holder 52 is pressurized by a confining pressure return pump 61 to a confining pressure of P IN +6mpa to suppress the flow of gas from the wall of the annulus between the core and the sheath. The back pressure of P OUT is applied to the back pressure valve 62 at the tail end of the core holder 52 by the confining pressure back pressure pump 61, so that a pressure environment similar to that of the underground aquifer is built in the core holder 52.
The constant pressure constant speed pump 1 is turned on, the first six-way valve 21 is turned on to connect the switch of the simulated flue gas intermediate container 43, and the valve of the simulated flue gas intermediate container 43 to connect the core holder 52 is turned on. Deionized water was injected into the simulated flue gas intermediate vessel 43 in a constant pressure mode (pressure P IN) to push the piston upward to inject the simulated flue gas therein into the core holder 52 at a pressure P IN. The pressure change of the two ends of the injection and production of the core holder 52 is monitored in real time through a differential pressure sensor, and the constant injection and production pressure difference of the two ends of the core holder 52 is realized through the linkage with the constant pressure constant speed pump 1.
The injected flue gas drives the migration of formation water in the core holder, and when the pressure at the end of the core holder 52 exceeds the back pressure P OUT, the back pressure valve 62 is opened, and formation water and flue gas are produced from the end of the core holder 52. After the produced gas-liquid mixture is subjected to gas-liquid separation by the gas-liquid separator 71, the liquid is measured and stored by the produced water meter. To prevent gas backflow, a check valve 73 is installed on the produced gas line. The separated gas passes through a one-way valve 73 and the instantaneous and cumulative flow rates are measured by a gas flow meter 74. Thereafter, the gas is fed into the multi-component gas on-line analyzer 72 for real-time on-line monitoring of the produced gas composition, thereby defining the produced gas composition and its variation with time. The final experimental exhaust gas is recovered and stored by the produced gas holding tank 75. And in the experimental process, the pressure and flow data of each experimental node are summarized into a data acquisition and analysis system for recording and processing.
(4) Examples
The target aquifer pressure was 21.8MPa, the aquifer temperature was 50 ℃, the aquifer landfill depth was 2200m, the aquifer permeability was 100mD, and the porosity was 0.18. And 4 short cores in the water-bearing layer drilling core are selected for splicing treatment, so that a long core with the total length of 18.5cm is obtained, and the total pore volume of the core is 1PV=16.34 ml.
The water type of the target aquifer region is CaCl 2 type, the total mineralization degree is 10.8g/L, and the specific mineral composition is shown in the following table:
TABLE 1 target aquifer formation water mineral composition
And preparing simulated formation water according to the mineral composition and mineralization degree of the formation water of the target aquifer. Meanwhile, based on the simulated flue gas preparation method, simulated flue gas with the molar fraction ratio of nitrogen to carbon dioxide being 7:3 is prepared.
The flue gas injection pressure P IN = 22.8MPa, the core holder 52 back pressure P OUT = 21.8MPa, and the core confining pressure 28.8MPa are set. The temperature of the incubator 51 was set to 50℃for the aquifer. The simulated flue gas was injected into the core at constant pressure at an injection pressure of P IN = 22.8MPa, and the injection was stopped when 1PV = 16.34ml was injected cumulatively. The production end fluid flow and composition changes of the core holder 52 are shown in fig. 12.
As can be seen from fig. 12, neither gas nor water is produced at the early stage of injection. This is because the back pressure valve 62 increases the pressure threshold for fluid production, and the fluid is in a hold-down phase within the core. Along with the gas injection, the pressure in the core is higher than the back pressure, and the water production is started at the output end. Overall, the large-scale water production stage is short in time, and when the accumulated injection flue gas reaches 0.34PV, the injection gas breaks through the core and is produced from the production end. After the gas-water co-production stage is carried out for a very short time, the core continuously produces a large amount of gas and no water is produced.
After the injected flue gas passes through the core to break through, the tail end of the core holder 52 starts to produce gas, and the components of the produced gas are monitored online in real time by the multi-component gas online analyzer 72, and the result is shown in fig. 13. As can be seen from fig. 13, the mole fraction of nitrogen in the produced gas in the early stage of gas production was higher than 0.7, and the mole fraction of carbon dioxide was lower than 0.3. This illustrates that simulated flue gas with a 7:3 mole fraction ratio of injected nitrogen to carbon dioxide, after seepage through the core of saturated formation water, changes in the composition of the flue gas, i.e., changes in the composition and distribution of the flue gas occur during the aquifer seepage.
In addition, by serially connecting a plurality of core holders 52, the total length of the core can be increased, thereby realizing experimental study of the influence of the aquifer plane distance on the separation of the flue gas components. Further, the overall length of the core holder 52 corresponds to the actual injection and production well spacing in the field, so that the influence rule of the injection and production well spacing on the separation of the flue gas components in the aquifer can be studied based on the method.
It can also be seen that if several core holders 52 are connected in parallel, the influence of the longitudinal factors of the aquifer, such as the rhythm, heterogeneity and inter-layer interference of the reservoir, can be simulated, so as to define the influence rule of the longitudinal factors of the multi-layer aquifer on the separation of the components of the flue gas.
Example 3 it is proposed on the basis of example 2 that example 3 includes all of the contents of example 2, and the advantageous effects of example 2 can be applied to example 3.
The invention provides an integrated method for separating nitrogen from flue gas and burying carbon dioxide by utilizing an underground aquifer, which comprises the following steps:
Step S100, well pattern deployment is carried out on a preset aquifer, a plurality of injection wells and extraction wells are distributed on the aquifer, the injection wells and the extraction wells are distributed at intervals, the injection wells and the extraction wells are distributed along a first direction to form one-dimensional linear flow or quasi-one-dimensional linear flow, wherein the permeability of the aquifer is greater than 50mD, the porosity is greater than 0.15 (namely 15%), and the thickness of the aquifer is greater than 10m;
in order to avoid polluting shallow water sources and improve the burying efficiency, carbon dioxide geological sequestration generally utilizes the supercritical physical characteristics of carbon dioxide to bury carbon dioxide in aquifers, for example aquifers below 800m from the ground surface. The aquifer temperature is typically above 31.1 ℃ and the pressure is above 7.38MPa below this depth, under which conditions the carbon dioxide is supercritical. The supercritical carbon dioxide has the characteristic of high density, so that the requirement of the carbon dioxide with unit mass on geological storage space is greatly smaller, and meanwhile, the supercritical carbon dioxide also has better fluidity, diffusivity and stronger dissolving capacity. During carbon dioxide injection, a portion of the carbon dioxide migrates upward to the top of the aquifer due to buoyancy, is blocked by the cap layer, collects at the top and flows to both sides. If there are some small scale geological structure traps in the aquifer, the carbon dioxide is pooled here, i.e. the structure is sequestered. A portion of the injected carbon dioxide will dissolve in the formation water and flow in dissolved form with the formation water, i.e., dissolve and sequester, through diffusion, dispersion, and transformation processes. Mineral sequestration begins to function when carbon dioxide comes into contact with surrounding rock minerals and undergoes a chemical reaction. When the injection of carbon dioxide is stopped, a portion of the carbon dioxide continues to migrate, with a small amount of carbon dioxide being trapped in the mineral surface or pore throat as residual gas. Because the stratum water flows quite slowly, the carbon dioxide can be ensured to be buried in the aquifer for a long time, so that the geological sequestration of the carbon dioxide is realized.
The aquifer selection can also comprise that the burial depth of the aquifer is h which is more than or equal to 1400m and less than or equal to 2400m; the fracture pressure of the aquifer rock is 1.5-2 times of the initial aquifer pressure; the thickness of the cover layer and the bottom layer of the water-containing layer is more than 10m, the permeability is less than 10 -4 mD, and the porosity is less than 0.1; the aquifer spreads smoothly, and the inclination angle is less than 5 degrees. In addition, the aquifer can also be in a anticline structure with good development, complete structure and no open fault or in a plane plate structure with a closed boundary; the water-bearing layer is preferably single lithology, has good sealing performance and avoids carbon dioxide leakage from polluting shallow domestic water.
Well pattern deployment may deploy a fluid-filled well pattern with a strip or planar reservoir as an example. When the well pattern is deployed, the narrow strip-shaped aquifer is deployed with a pair of injection and production wells, and the planar plate-shaped aquifer is deployed with an injection well row and a production well row, so that the flow mode of fluid in the reservoir is one-dimensional linear flow or quasi-one-dimensional linear flow.
In the embodiment of the invention, a pair of injection and production wells are deployed by adopting a narrow strip reservoir, the pressure of the water-bearing layer is 21.8MPa, the temperature of the water-bearing layer is 50 ℃, the burying depth of the water-bearing layer is 2200m, the air-water interface is located at 2150m, the permeability of the water-bearing layer is 100mD, the porosity is 0.18, and the well spacing is set to 500m. The well spacing should be between 300m and 800m in field applications, depending on the connectivity of the reservoir. In the case of a multi-layer reservoir, a separate injection and separate production mode is preferred.
Specifically, the step of performing well pattern deployment on a preset aquifer comprises the following steps:
deploying a pair of injection and production wells for the narrow strip-shaped aquifer;
and deploying an injection well row and a production well row for the planar platy aquifer.
In addition, the aquifer burying depth in step S100 may be determined by optimizing the aquifer burying depth by a method including:
Calculating the corresponding specific volume of the gas according to the temperature and pressure conditions;
；
Wherein P is the gas pressure;
t is the gas temperature;
V is the specific volume of the gas;
r is the gas constant, r= 8.314 kJ/(kmol·k);
a (T), b are critical temperature and pressure functions;
；
；
；
；
Alpha and m are both calculation coefficients;
p c is the gas critical pressure;
T c is the critical temperature of the gas;
omega is the gas eccentricity factor;
and determining the buried depth of the aquifer according to the specific volume of the gas.
As the depth of the aquifer is increased, both the reservoir temperature and pressure increase. An increase in temperature will cause expansion of the injected gas, while an increase in pressure will cause compression of the injected gas, the temperature and pressure effects on the volume of the injected gas being repulsive. From the aspect of the burying amount, the high temperature is unfavorable for burying the carbon dioxide, and the high pressure is favorable for burying the carbon dioxide. Therefore, as the depth of the buried water layer increases, which factor of temperature and pressure is the main factor, how to optimize the range of the buried water layer to maximize the carbon dioxide buried amount is an objective problem to be solved. For an aquifer, its temperature and pressure vary with depth. For different aquifers, the temperature and pressure change rules are different along with the increase of depth, namely the ground temperature gradient and the pressure coefficient are different, specifically, the following formula is adopted
；
Wherein P 0 is the surface pressure;
P is the pressure at the h position of the burying depth of the water-bearing layer;
epsilon is the aquifer pressure coefficient and is the aquifer attribute parameter;
h is the buried depth of the aquifer.
；
Wherein T 0 is the surface temperature;
t is the temperature at which the burying depth of the water-bearing layer is h;
beta is the earth temperature gradient of the aquifer and is the attribute parameter of the aquifer.
The gas specific volume function f (V) is as follows:
；
The specific volume V of the gas when the function f (V) =0 is the solution of the equation. Therefore, the Newton iteration method is adopted to continuously and circularly update V, so that f (V) approaches to 0, and the actual specific volume of the gas is obtained. The specific iteration formula is as follows:
；
Where n is the number of iterations.
Based on the formula and the solving thought, the numerical calculation of the specific volume of the gas under different temperature and pressure conditions can be realized by assigning the known specific volume of the gas under the standard condition as an iteration initial value and setting the iteration times and the cut-off precision.
In order to facilitate understanding, the calculated result of the specific volume of the nitrogen gas is counted down in the drawing process, namely the density of the nitrogen gas. A plot of nitrogen density as a function of aquifer depth is shown in fig. 14. As can be seen from fig. 14, the early increase in nitrogen density was slightly faster and the later region was gentle as the depth of the aquifer increased, and the two had an approximately linear correlation as a whole. As the depth of the aquifer increases, the nitrogen density gradually increases, and the mass of nitrogen buried per unit void space also increases.
Similarly, the numerical calculation was performed on the law of the specific volume of carbon dioxide gas changing with the buried depth of the aquifer by the method described above, and the results are shown in fig. 15.
As can be seen from fig. 15, as the depth of the aquifer increases, the density of carbon dioxide rapidly increases in the interval of 0-1400m, and the phase transition process from the gaseous state to the supercritical state of carbon dioxide promotes the great increase of the density of carbon dioxide; in the interval 1400-2400m, the density of carbon dioxide is slowly increased, the formation pressure is the main control factor, and the density is increased due to the compression of carbon dioxide; in the 2400-4000m range, the density of the carbon dioxide is slightly increased, which indicates that the compression capacity of the supercritical carbon dioxide under the action of high temperature tends to be limited. Therefore, the optimum carbon dioxide sequestration depth for this aquifer is in the range 1400-2400 m. In this region, the density of carbon dioxide is high, and the carbon dioxide storage amount per unit pore space is large. The increase of the burying depth is continued, the increment of the burying amount of the carbon dioxide is tiny, the cost of drilling operation and the like can be increased along with the increase of the depth, and the economic benefit is reduced along with the increase of the depth.
Step S200, after the flue gas is injected from the injection well for a preset time period, injecting liquid and keeping the bottom hole pressure unchanged;
In the embodiment of the invention, the injection well is arranged to inject the flue gas for 60 days, and the flue gas consists of two components of carbon dioxide with the mole fraction of 0.3 and nitrogen with the mole fraction of 0.7. The injection well is controlled to always keep constant flow injection, the injection speed of the flue gas of the injection well is constant at 1000m 3/day, and the upper limit of the bottom hole pressure is 44.5MPa. After continuous gas injection for 60 days, gas injection is stopped and water injection is started, the water injection speed of the injection well is constant at 10m 3/day, and the bottom hole pressure control condition of the injection well is kept unchanged. In other embodiments, it may be set according to specific needs, and is not limited herein.
Step S300, when the production well starts to produce gas, controlling the bottom hole flow pressure of the production well to be kept at a first preset pressure;
In the embodiment of the invention, the drainage operation is performed after the extraction well starts from gas injection of the injection well until the gas slug is moved to the extraction well, the gas production operation is performed after the extraction well is started, the bottom hole flow pressure of the extraction well is controlled to be always kept at 8MPa in the process, the production is performed in a fixed bottom hole flow pressure mode, and the upper limit of the ground liquid production amount is set to be 1000m 3/day. In other embodiments, the configuration may be set according to specific requirements, and is not particularly limited herein.
And step S400, when the mole fraction of the nitrogen produced by the production well is lower than a first preset value, closing the production well and simultaneously closing the injection well.
In this embodiment, the drainage operation is performed all the time from the gas injection of the injection well, that is, after 104 days of production, that is, after 44 days of water injection of the injection well, the gas production is started, and at this time, the gas production rate reaches the maximum value, the mole fraction of nitrogen in the produced gas is 1, and the mole fraction of carbon dioxide is 0, as shown in fig. 2.
As can be seen from fig. 2 and 3, as production proceeds, the gas production rate begins to gradually decrease, the mole fraction of carbon dioxide in the produced gas from the production well gradually increases, and the mole fraction of nitrogen gradually decreases. This is due to the significant difference in the migration rates of carbon dioxide and nitrogen when the gas slugs are transported in the aquifer, the migration rate of nitrogen being greater than the migration rate of carbon dioxide. When the gas slug is moved to the production well, nitrogen is mainly located in the first half of the gas slug, and carbon dioxide is mainly located in the second half of the gas slug. Therefore, the phenomenon that the nitrogen gas firstly produces carbon dioxide and then produces the carbon dioxide shown in fig. 4 occurs, so that the nitrogen gas and the carbon dioxide are effectively separated. Further, the separation efficiency of nitrogen can be improved to the maximum extent by reasonably controlling the well closing time.
In this embodiment, when the mole fraction of nitrogen produced by the production well is lower than 0.95, the production well is closed, and at this time, the separation efficiency of nitrogen is higher, so that the separation efficiency of nitrogen in flue gas and the sequestration efficiency of carbon dioxide are improved.
In the embodiment of the invention, when the production of the production well is carried out for 142 days, namely, when the water is injected into the injection well for 82 days, the mole fraction of carbon dioxide in the produced gas is 0.053, the mole fraction of nitrogen is 0.946, as shown in fig. 2, 3 and 4, at the moment, the gas production speed of the production well is 584m 3/day, the mole flow rate of the nitrogen is 23.525 ×10 3 mol/day, and the mole flow rate of the carbon dioxide is 1.136×10 3 mol/day. As can be seen from fig. 2 and 4, the molar flow rate of nitrogen is almost consistent with the gas production rate from the beginning of the drainage operation of the production well to 142 days of the production well, which indicates that the production of carbon dioxide from the production well is very little and can be almost ignored. At this time, the production is stopped by closing the production well, so that nitrogen can be separated from flue gas to the greatest extent and returned to the atmosphere again, and injected carbon dioxide is retained in the aquifer, thereby realizing effective separation of nitrogen and geological storage of carbon dioxide.
In this embodiment, the first preset value is 0.95, and in other embodiments, the setting of the first preset value may be determined according to the following manner, specifically, before the step S200, after the step S100, the method further includes:
step S510, obtaining nitrogen separation rates at different temperatures and pressures by changing the temperature and the pressure of the aquifer based on the experimental method of the component separation of the flue gas in the aquifer;
step S520, constructing a nitrogen separation efficiency plate according to nitrogen separation rates at different temperatures and pressures;
Step S530, determining turning points of nitrogen separation efficiency change according to the constructed nitrogen separation efficiency plate;
step S540, according to the determined turning point, the first aquifer pressure, the first aquifer temperature and the first separation efficiency in the optimal state are determined.
After step S540, before step S200, the method includes:
And step S550, adjusting the aquifer pressure and the aquifer temperature of the aquifer according to the determined first aquifer pressure and first aquifer temperature.
It should be noted that, steps S510 to S550 may also be performed before step S100, which is not particularly limited herein.
Specifically, the first separation efficiency is nitrogen separation efficiency, and the nitrogen separation efficiency is the ratio of the mass of nitrogen produced by a production well to the total mass of injected nitrogen in the current burying process of the flue gas aquifer.
Nitrogen separation efficiency is defined as: and in the process of burying the flue gas aquifer, the ratio of the mass of nitrogen produced by the production well to the total mass of injected nitrogen.
；（1）
Wherein m Nitrogen gas - Extraction of is the mass of nitrogen produced by the production well; m Nitrogen gas - The injection is the mass of the injected nitrogen .
Defining the carbon dioxide sequestration efficiency as: and in the process of burying the flue gas aquifer, the ratio of the mass of carbon dioxide buried in the aquifer to the total mass of carbon dioxide injected.
；（2）
Wherein m CO2- Buried storage is the total mass of carbon dioxide buried in the aquifer; m CO2- Injection into a cavity is the total mass of carbon dioxide injected.
The nitrogen separation efficiency under different temperature and pressure conditions was obtained by changing the temperature and pressure of the aquifer in the numerical simulation model, respectively, and were collectively plotted as a plate, as shown in fig. 11. As can be seen from the figure, as the pressure increases, the nitrogen separation efficiency increases slowly and then decreases sharply, and there is a distinct turning point. Meanwhile, as the temperature rises, the pressure corresponding to the turning point increases, and the turning point moves along with the temperature change. According to the plate, the optimal condition of nitrogen separation efficiency is that the pressure of an aquifer is 12MPa, the temperature of the aquifer is 40 ℃, at this time, the nitrogen separation efficiency can reach 74%, and the separation effect is best.
Based on the method, the nitrogen separation efficiency under different temperature and pressure conditions can be obtained aiming at the actual temperature and pressure of different aquifers of the mine, so that a nitrogen separation efficiency chart under different aquifer temperatures and aquifer pressures is constructed, and the influence rule of the aquifer stratum temperature and stratum pressure on the flue gas component separation efficiency is further defined. Based on the above, according to the temperature and pressure conditions of the potential target buried aquifer, the corresponding nitrogen separation efficiency can be obtained by checking the corresponding plate, so that the accurate prediction of the nitrogen separation efficiency in the flue gas in the determined temperature and pressure range is realized.
According to the integrated method for separating nitrogen from flue gas and burying carbon dioxide by utilizing the underground aquifer, well pattern deployment is carried out on the preset aquifer, a plurality of injection wells and extraction wells are distributed on the aquifer, the injection wells and the extraction wells are distributed at intervals, and the injection wells and the extraction wells are distributed along a first direction to form one-dimensional linear flow or quasi-one-dimensional linear flow, wherein the permeability of the aquifer is greater than 50mD, the porosity is greater than 0.15, and the thickness of the aquifer is greater than 10m; controlling the injection of flue gas from an injection well to reach a preset duration, injecting liquid and keeping the bottom hole pressure unchanged; when the production well starts to produce gas, controlling the bottom hole flow pressure of the production well to be kept at a first preset pressure; when the mole fraction of the nitrogen produced by the production well is lower than a first preset value, closing the production well, and simultaneously closing the injection well, so that the separation and burying efficiency is high, the energy consumption is low and the cost is low;
further, the flue gas is injected from the injection well, and the two components are separated in the transportation process of the water-bearing layer under the combined action of the difference of the gas phase transportation speed and the liquid phase transportation speed and the difference of the solubility of the carbon dioxide and the nitrogen in the stratum water. In the process, nitrogen moves to the front part of the gas slug, and carbon dioxide is positioned at the rear part, so that the nitrogen reaches a production well and is produced, and the carbon dioxide is retained in an aquifer and is sealed;
Further, compared with the traditional mode of stepwise carrying out ground separation and underground burying of the flue gas, the invention reduces the requirements of ground flue gas component separation equipment, improves the separation and burying efficiency and reduces the cost of separation and burying.
The invention also provides a prediction method of nitrogen separation rate in flue gas component separation by using the underground aquifer, wherein the method for flue gas component separation by using the underground aquifer comprises the following steps:
and step S600, searching the corresponding nitrogen separation rate according to the temperature and pressure of the current aquifer and a pre-established nitrogen separation efficiency chart.
In order to further illustrate the principles of the integrated method for nitrogen separation and carbon dioxide sequestration in flue gas using an underground aquifer provided by the present invention, specific examples are described below.
(1) Distribution law of gas slugs in production middle period
It should be noted that, the gas slug is a gas segment in which flue gas is in a supercritical state or a gaseous state in an aquifer, and when fluid is injected into an injection well, a liquid-gas-liquid distribution is formed in the aquifer, and the gas segment is called a gas slug.
Taking 90 days of production of the injection and production well as an example, at this time, the injection of flue gas is completed, the injection well is started to inject water for 30 days later, the gas slug is moved to the middle parts of the injection well and the production well, the injection gas is not broken through, the production well does not see gas (the gas production speed is 0), and the production well still performs drainage operation. It can be seen from the gas saturation that the flue gas slugs are concentrated mainly between 170m and 360m from the injection well, as shown in fig. 5.
(2) Distribution law of each gas component in gas slugs
As can be seen from fig. 6, the mole fraction of nitrogen at near injection well and production well, i.e., 0 to 100m and 300m to 375m from the injection well, is approximately 0.75 at 100m to 300m from the injection well, and the mole fraction of carbon dioxide at 100m to 300m from the injection well is around 0.25.
As can be seen from comparing fig. 6,7, and 8, the mole fraction of carbon dioxide and nitrogen in the gas phase is almost the same as the mole fraction of the whole, and the difference occurs mainly in the aqueous phase. The mole fraction of nitrogen in the aqueous phase at 0 to 375m from the injection well was 0.001, while the mole fraction of carbon dioxide in the aqueous phase at 100 to 300m from the injection well was nearly 0.01, indicating that the solubility of both carbon dioxide and nitrogen in water was small, but the solubility of carbon dioxide was about 10 times that of nitrogen. The frequent dissolution and precipitation of carbon dioxide reduces its migration rate relative to nitrogen, so that the injection into the flue gas slug is predominantly nitrogen in the front and carbon dioxide in the rear. The most part of the produced gas in the early gas production stage of the production well is nitrogen, carbon dioxide is partially dissolved in the formation water, the carbon dioxide slowly flows along with the formation water, and undissolved parts are retained in the aquifer in a gaseous state or a supercritical state.
(3) Gas-liquid two-phase seepage velocity comparison
As can be seen from fig. 9, the gas-liquid two phases have different flows, and the gas phase has higher saturation and lower saturation at the gas slug, the relative permeability of the gas phase is greater than that of the liquid phase, and the viscosity of the gas phase is smaller than that of the liquid phase, so that the seepage velocity of the gas phase is far greater than that of the liquid phase.
Calculating the flow rate of the production well:
；（3）
and deducing a seepage velocity calculation formula of the available gas phase and liquid phase according to the formula (3).
Calculation of gas phase seepage velocity:
；（4）
calculation of liquid phase seepage velocity:
；（5）
Based on the above formula, the permeability, viscosity, pressure gradient of the water-bearing layer and other data of the gas phase and the liquid phase are substituted, and the law of the variation of the seepage speed of the gas phase and the liquid phase along with the number of the injection and production well intervals when the production well is produced for 90 days can be obtained through calculation, and the law is specifically shown in fig. 10. The permeation rate of the gas phase is almost 0 at 0 to 150m and 375m to 500m from the injection well, and 45 μm/s at 150m to 375m from the injection well, i.e. at the gas slug; the law of variation of the seepage velocity of the liquid phase and the gas phase is just opposite, the seepage velocity is 48 mu m/s at the injection well distance of 0 to 150m from the injection well, 55 mu m/s can be reached at the injection well distance of 375m to 500m from the injection well, and only 10 mu m/s is reached at the injection well distance of 150m to 375m, namely at the gas slug. The mole fraction of carbon dioxide and nitrogen in the gas phase is nearly identical to the overall mole fraction, with differences being predominantly manifested in the solubility differences in the liquid phase. The solubility of carbon dioxide is much greater than that of nitrogen, and the dissolved carbon dioxide content of formation water is much greater than that of nitrogen, so the carbon dioxide content of the gas phase is lower than that of nitrogen. When the gas slug moves to the middle part of the reservoir, the gas phase seepage velocity is about 5 times of the liquid phase seepage velocity, so that the carbon dioxide moving velocity is slightly lower than the nitrogen moving velocity under the influence of dissolution. Along with the continuous migration of the gas slugs, the difference of the migration speed is accumulated continuously, so that the separation phenomenon of carbon dioxide and nitrogen components is generated.
In summary, due to the difference of the gas phase and the liquid phase migration velocity and the solubility difference of carbon dioxide and nitrogen in formation water, the two components are separated in the flue gas migration process of the aquifer under the combined action, the nitrogen is positioned at the front part of the gas slug, and the carbon dioxide is positioned at the rear part. The method leads to that most of the gas produced in the early stage of the gas production operation of the production well is nitrogen, part of the carbon dioxide is dissolved in the formation water and exists in a dissolved state, and the undissolved part is retained in an aquifer in a gaseous state or a supercritical state, so that the effective separation of the nitrogen and the carbon dioxide in the flue gas and the burying of the carbon dioxide are realized.
It will be apparent that the embodiments described above are merely some, but not all, embodiments of the invention. Based on the embodiments of the present invention, those skilled in the art may make other different changes or modifications without making any creative effort, which shall fall within the protection scope of the present invention.
Claims (7)
1. An experimental device for separating components of flue gas in an aquifer is characterized by comprising a constant pressure constant speed pump, a first six-way valve, a second six-way valve, a third six-way valve, a nitrogen intermediate container, a carbon dioxide intermediate container, a nitrogen flow controller, a carbon dioxide flow controller, a simulated flue gas intermediate container, a constant temperature box, a core holder, a confining pressure back pressure pump, a back pressure valve, a gas-liquid separator, a produced water meter, a one-way valve, a gas flowmeter, a produced gas storage tank, a first two-way valve and a second two-way valve;
The constant-pressure constant-speed pump is connected with the first end of the first six-way valve, the second end of the first six-way valve is connected with one end of the nitrogen intermediate container, and the other end of the nitrogen intermediate container is sequentially connected with the nitrogen flow controller and one end of the first two-way valve; the third end of the first six-way valve is connected with one end of the carbon dioxide intermediate container, the other end of the carbon dioxide intermediate container is sequentially connected with the carbon dioxide flow controller and one end of the second bi-directional valve, and the other end of the first bi-directional valve is connected with the other end of the second bi-directional valve and then is connected with the first end of the second six-way valve; the lower end of the simulated flue gas intermediate container is connected with the fourth end of the first six-way valve, and the upper end of the simulated flue gas intermediate container is connected with the second end of the second six-way valve; the third end of the second six-way valve is connected with the first end of the core holder, and the core holder is arranged in the incubator; the middle part of the core holder is connected with the first end of the third six-way valve, the second end of the third six-way valve is connected with the confining pressure back pressure pump, the third end of the third six-way valve is connected with the first end of the back pressure valve, the second end of the core holder is connected with the second end of the back pressure valve, and the third end of the back pressure valve is connected to the first end of the gas-liquid separator; the second end of the gas-liquid separator is sequentially connected with a one-way valve, a gas flowmeter and a produced gas storage tank; and the third end of the carbon dioxide intermediate container is connected with a produced water meter.
2. A method of testing the separation of components of a flue gas in an aquifer, using the test apparatus of claim 1, the method comprising:
Preparing simulated flue gas through a nitrogen intermediate container and a carbon dioxide intermediate container, wherein the simulated flue gas enters the simulated flue gas intermediate container, and nitrogen and carbon dioxide in the simulated flue gas are in a preset proportion;
Placing the rock core after saturation of stratum water into a rock core holder, and then placing the rock core holder into an incubator so as to enable two ends of the rock core holder to be closed and constant in temperature, thereby simulating the temperature condition of an underground aquifer;
Applying P IN +6MPa preset confining pressure to the core holder through a confining pressure back pressure pump, and applying P OUT preset back pressure to a back pressure valve at the tail end of the core holder through the confining pressure back pressure pump so as to build a pressure environment similar to or the same as an underground aquifer in the core holder;
Opening a constant-pressure constant-speed pump, a first six-way valve, a switch of a simulated flue gas intermediate container and a valve switch connected with a core holder, injecting deionized water into the simulated flue gas intermediate container in a constant-pressure mode, pushing a piston in the simulated flue gas intermediate container to move upwards to inject simulated flue gas into the core holder at P IN pressure, monitoring pressure changes at two injection and extraction ends of the core holder in real time, and realizing constant injection and extraction pressure difference at two ends of the core holder through communication with the constant-pressure constant-speed pump;
Injecting flue gas to drive stratum water in the core to move, when the pressure at the tail end of the core holder exceeds back pressure P OUT, opening a back pressure valve, producing stratum water and flue gas from the tail end of the core holder, carrying out gas-liquid separation on the produced gas-liquid mixture through a gas-liquid separator, and metering and storing liquid through a produced water metering instrument; the separated gas passes through a one-way valve, the instantaneous and accumulated flow is measured by a gas flowmeter, and the produced gas component is monitored on line in real time, so that the produced gas component and the change of the produced gas component along with time are clear.
3. The method of claim 2, wherein the experiment of the influence of the aquifer plane and longitudinal factors on the separation of the components of the flue gas is achieved by increasing the number of core holders and by different connection means.
4. The method of claim 3, wherein the number of core holders is a plurality of the method of separating components of the flue gas in the aquifer,
The plurality of core holders are arranged in series, the total length of the core is increased, and the total length of the plurality of core holders corresponds to the actual injection and production well distance in the field, so that experiments are carried out on the influence of the plane distance of the aquifer on the separation of the components of the flue gas; or alternatively
The core holders are arranged in parallel to simulate the longitudinal factors of the aquifer so as to determine the influence rule of the longitudinal factors of the aquifer of the multi-layer system on the separation of the components of the flue gas.
5. An integrated method for separating nitrogen from carbon dioxide in flue gas by using an underground aquifer, comprising the following steps:
Well pattern deployment is carried out on a preset aquifer, a plurality of injection wells and extraction wells are distributed on the aquifer, the injection wells and the extraction wells are distributed at intervals, the injection wells and the extraction wells are distributed along a first direction to form one-dimensional linear flow or quasi-one-dimensional linear flow, wherein the permeability of the aquifer is greater than 50mD, the porosity is greater than 0.15, and the thickness of the aquifer is greater than 10m;
Controlling the injection of flue gas from an injection well to reach a preset duration, injecting liquid and keeping the bottom hole pressure unchanged;
when the production well starts to produce gas, controlling the bottom hole flow pressure of the production well to be kept at a first preset pressure;
When the mole fraction of the nitrogen produced by the production well is lower than a first preset value, closing the production well and simultaneously closing the injection well;
wherein the first preset value is determined from experimental data obtained from an experimental method for the separation of components of a flue gas in an aquifer according to any one of claims 2 to 4.
6. The integrated method for nitrogen separation and carbon dioxide sequestration in flue gas using an underground aquifer of claim 5, wherein the step of controlling injection of the flue gas from the injection well for a predetermined period of time, injecting the liquid and maintaining the bottom hole pressure unchanged, is preceded by the step of performing well pattern deployment of the predetermined aquifer, the method further comprising:
Based on the experimental method of the component separation of the flue gas in the aquifer, the nitrogen separation rate under different temperatures and pressures is obtained by changing the temperature and the pressure of the aquifer;
Constructing a nitrogen separation efficiency plate according to nitrogen separation rates at different temperatures and pressures;
determining turning points of nitrogen separation efficiency change according to the constructed nitrogen separation efficiency plate;
And determining the first aquifer pressure, the first aquifer temperature and the first separation efficiency in the optimal state according to the determined turning points.
7. The integrated method for nitrogen separation and carbon dioxide sequestration in flue gas using an underground aquifer of claim 5, wherein the well pattern deployment is performed in a predetermined aquifer, a plurality of injection wells and extraction wells are arranged in the aquifer, the injection wells and the extraction wells are arranged at intervals, and the plurality of injection wells and extraction wells are arranged along a first direction to form a one-dimensional linear flow or a quasi-one-dimensional linear flow, further comprising:
optimizing the buried depth of the aquifer, wherein the optimizing method comprises the following steps:
Calculating the corresponding specific volume of the gas according to the temperature and pressure conditions;
；
Wherein P is the gas pressure;
t is the gas temperature;
V is the specific volume of the gas;
r is the gas constant, r= 8.314 kJ/(kmol·k);
a (T), b are critical temperature and pressure functions;
；
；
；
；
Alpha and m are both calculation coefficients;
p c is the gas critical pressure;
T c is the critical temperature of the gas;
omega is the gas eccentricity factor;
and determining the buried depth of the aquifer according to the specific volume of the gas.
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