CN116201598A - Carbon dioxide sealing method and sealing system - Google Patents
Carbon dioxide sealing method and sealing system Download PDFInfo
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- CN116201598A CN116201598A CN202211564835.0A CN202211564835A CN116201598A CN 116201598 A CN116201598 A CN 116201598A CN 202211564835 A CN202211564835 A CN 202211564835A CN 116201598 A CN116201598 A CN 116201598A
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- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 title claims abstract description 138
- 229910002092 carbon dioxide Inorganic materials 0.000 title claims abstract description 69
- 239000001569 carbon dioxide Substances 0.000 title claims abstract description 69
- 238000007789 sealing Methods 0.000 title claims abstract description 47
- 238000000034 method Methods 0.000 title claims abstract description 34
- 238000002347 injection Methods 0.000 claims abstract description 103
- 239000007924 injection Substances 0.000 claims abstract description 103
- 239000007788 liquid Substances 0.000 claims abstract description 50
- WNXJIVFYUVYPPR-UHFFFAOYSA-N 1,3-dioxolane Chemical compound C1COCO1 WNXJIVFYUVYPPR-UHFFFAOYSA-N 0.000 claims abstract description 46
- 238000006703 hydration reaction Methods 0.000 claims abstract description 46
- 238000003860 storage Methods 0.000 claims abstract description 43
- 238000012544 monitoring process Methods 0.000 claims abstract description 26
- VTVVPPOHYJJIJR-UHFFFAOYSA-N carbon dioxide;hydrate Chemical compound O.O=C=O VTVVPPOHYJJIJR-UHFFFAOYSA-N 0.000 claims abstract description 23
- 239000007864 aqueous solution Substances 0.000 claims abstract description 15
- 230000008569 process Effects 0.000 claims abstract description 10
- 238000006243 chemical reaction Methods 0.000 claims abstract description 7
- 230000009919 sequestration Effects 0.000 claims description 27
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 21
- 230000015572 biosynthetic process Effects 0.000 claims description 14
- 238000012806 monitoring device Methods 0.000 claims description 9
- 239000000243 solution Substances 0.000 claims description 8
- 238000005086 pumping Methods 0.000 claims description 4
- 239000004215 Carbon black (E152) Substances 0.000 claims description 2
- 229930195733 hydrocarbon Natural products 0.000 claims description 2
- 150000002430 hydrocarbons Chemical class 0.000 claims description 2
- 230000014759 maintenance of location Effects 0.000 claims 1
- 239000007789 gas Substances 0.000 description 70
- 239000012071 phase Substances 0.000 description 13
- 239000007791 liquid phase Substances 0.000 description 11
- 238000005755 formation reaction Methods 0.000 description 10
- 238000009792 diffusion process Methods 0.000 description 7
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 6
- 229910052799 carbon Inorganic materials 0.000 description 6
- 239000011148 porous material Substances 0.000 description 6
- 238000004090 dissolution Methods 0.000 description 4
- 239000002994 raw material Substances 0.000 description 4
- 230000000694 effects Effects 0.000 description 3
- 239000005431 greenhouse gas Substances 0.000 description 3
- 238000005191 phase separation Methods 0.000 description 3
- 239000002699 waste material Substances 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- RAHZWNYVWXNFOC-UHFFFAOYSA-N Sulphur dioxide Chemical compound O=S=O RAHZWNYVWXNFOC-UHFFFAOYSA-N 0.000 description 2
- 230000006978 adaptation Effects 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 239000013043 chemical agent Substances 0.000 description 2
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- 238000005253 cladding Methods 0.000 description 2
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- 238000005516 engineering process Methods 0.000 description 2
- 230000007613 environmental effect Effects 0.000 description 2
- 238000003912 environmental pollution Methods 0.000 description 2
- 150000004677 hydrates Chemical class 0.000 description 2
- 230000036571 hydration Effects 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 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 description 2
- 238000012986 modification Methods 0.000 description 2
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- 230000009467 reduction Effects 0.000 description 2
- 230000001502 supplementing effect Effects 0.000 description 2
- 238000010521 absorption reaction Methods 0.000 description 1
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 1
- 239000003245 coal Substances 0.000 description 1
- 125000004122 cyclic group Chemical group 0.000 description 1
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- 238000005272 metallurgy Methods 0.000 description 1
- VUZPPFZMUPKLLV-UHFFFAOYSA-N methane;hydrate Chemical compound C.O VUZPPFZMUPKLLV-UHFFFAOYSA-N 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 229910052760 oxygen Inorganic materials 0.000 description 1
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- 230000037361 pathway Effects 0.000 description 1
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- 239000000126 substance Substances 0.000 description 1
- 238000010792 warming Methods 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21F—SAFETY DEVICES, TRANSPORT, FILLING-UP, RESCUE, VENTILATION, OR DRAINING IN OR OF MINES OR TUNNELS
- E21F17/00—Methods or devices for use in mines or tunnels, not covered elsewhere
- E21F17/16—Modification of mine passages or chambers for storage purposes, especially for liquids or gases
-
- C—CHEMISTRY; METALLURGY
- C01—INORGANIC CHEMISTRY
- C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
- C01B32/00—Carbon; Compounds thereof
- C01B32/50—Carbon dioxide
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/0099—Equipment or details not covered by groups E21B15/00 - E21B40/00 specially adapted for drilling for or production of natural hydrate or clathrate gas reservoirs; Drilling through or monitoring of formations containing gas hydrates or clathrates
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
- Y02C20/00—Capture or disposal of greenhouse gases
- Y02C20/40—Capture or disposal of greenhouse gases of CO2
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- General Life Sciences & Earth Sciences (AREA)
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- Environmental & Geological Engineering (AREA)
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Abstract
The invention discloses a carbon dioxide sealing method and a sealing system. The sealing method comprises the following steps: (1) Injecting an aqueous solution of 1, 3-dioxolane into a target geological region; (2) And injecting gas to be sequestered into the target geological region, and generating carbon dioxide hydrate through reaction. The sealing system comprises a monitoring unit, a conveying unit and a hydration reaction unit; the conveying unit is connected with the hydration reaction unit; the conveying unit comprises a horizontal liquid injection well and a horizontal gas injection well; the monitoring unit includes a horizontal monitoring well. The carbon dioxide sealing method and the sealing system provided by the invention realize the carbon dioxide sealing process under a large-scale scene by using the thermodynamic and kinetic double-promoter 1, 3-dioxolane, and realize high-efficiency, rapid and environment-friendly CO 2 And (5) geological storage.
Description
Technical Field
The invention relates to the technical field of carbon dioxide sealing and storage, in particular to a carbon dioxide sealing and storage method and a sealing and storage system.
Background
Carbon dioxide is a greenhouse gas, and is a major factor in global warming. With the rapid development of socioeconomic performance, the carbon dioxide emissions produced by industrial production and human activities are increasing, and the trend of continuously increasing the greenhouse effect seriously threatens the climate balance and the ecological environment. How to effectively control and reduce the emission of greenhouse gas carbon dioxide has become a serious problem faced by countries around the world. In addition to reducing direct utilization of carbon-based energy sources, CO 2 Geological sequestration is another pathway for carbon dioxide emissions reduction that CO 2 Capturing from energy-intensive industrial emission sources such as coal electricity, metallurgy and the like, injecting into deep geological structures (deep ground, seabed, depleted petroleum and natural gas reservoirs and the like) for CO sequestration 2 The direct emission of carbon dioxide gas to the atmosphere is avoided, and the method is an important development direction in the fields of carbon dioxide emission reduction and greenhouse gas treatment. Wherein the hydrate method is CO 2 Sequestration is a leading-edge geological sequestration technique that sequesters CO 2 Injection into an aqueous geologic structure having suitable thermodynamic conditions to form solid CO in the pores of a porous medium 2 A hydrate. Due to CO 2 The hydrate has high carbon storage density and excellent mechanical property, and the technology can realize stable and long-term CO 2 Sealing and storing.
However, hydrate process CO 2 The sealing technology still has bottleneck problems before large-scale application. First, CO 2 The generation of hydrate has more severe requirements on thermodynamic conditions, and CO 2 Hydrate is difficult to stably fix and store in a geological structure with higher temperature, and meanwhile, CO is caused in the sealing process 2 Slow kinetics of hydrate formation and ultimately limiting CO 2 A sealing amount. These problems require researchers to find and develop efficient and environmentally friendly hydrate thermodynamic promotersTo improve CO 2 Thermodynamic conditions and dynamic properties of hydrate formation, and the carbon storage capacity of the geological structure is improved. In addition, the presence of gas-liquid seepage and component diffusion within the geologic porous media may result in a heterogeneous distribution of hydrate promoters that is not compatible with water and CO 2 Is sufficiently miscible and difficult to be efficiently used for CO 2 The hydrate is sequestered and even causes diffusion of chemical agents and environmental pollution. Therefore, there is a need to find new engineering methods to make the best use of hydrate promoters injected into the formation for efficient use in CO 2 Sealing and storing, reducing raw material waste and environmental pollution.
Disclosure of Invention
Aiming at the technical problems, the invention provides a carbon dioxide sealing method and a sealing system, which realize a carbon dioxide sealing process under a large-scale scene by using a thermodynamic and kinetic double-promoter 1, 3-dioxolane, and realize high-efficiency, rapid and environment-friendly CO 2 And (5) geological storage.
In order to achieve the above purpose, the technical scheme adopted by the invention is as follows:
in one aspect, the present invention provides a carbon dioxide sequestration method, comprising the steps of:
(1) Injecting an aqueous solution of 1, 3-dioxolane into a target geological region;
(2) And injecting gas to be sequestered into the target geological region, and generating carbon dioxide hydrate through reaction.
In the step (2), after the gas to be sequestered is injected, the difference between the pressure in the target geological area and the initial pressure is less than or equal to 1.0MPa;
in certain embodiments, the injecting of the gas to be sequestered into the target geological region in step (2) is repeated a plurality of times; specifically, after generating carbon dioxide hydrate through reaction, the pressure in the target geological region is lower than the original stratum pressure by 3.0MPa, and the operation of injecting gas to be sealed into the target geological region is repeated;
preferably, in the step (2), the stage of diffusing the 1, 3-dioxolane aqueous solution is further included before the gas to be sequestered is injected;
preferably, in the last repetition of the operation of injecting the gas to be sequestered into the target geological region, the pressure in the target geological region is maintained for 6-12 months at the initial formation pressure (+ -0.5 MPa) by adopting a continuous gas injection mode; in the technical scheme of the invention, continuous gas injection promotes the phase separation of the unused 1, 3-dioxolane aqueous solution in the target geological region, so that the aqueous solution phase rich in 1, 3-dioxolane further seals carbon dioxide in a liquid phase form.
As a preferred embodiment, the method further comprises post-treatment, wherein the post-treatment is to fix the target geological region;
preferably, the target geological region is sealed after the pressure of the target geological region is not lower than the initial pressure and is stable.
In certain embodiments, the target geological region is an aqueous formation, a subsea formation, or an aqueous abandoned hydrocarbon reservoir having suitable thermodynamic conditions for the formation of carbon dioxide hydrates;
preferably, the maximum temperature within the target geological region does not exceed 15 ℃;
preferably, the initial pressure within the target geological region is not less than 2.5MPa.
In some specific embodiments, the target geological region should meet the characteristics of having a large internal space, large porosity, low permeability and good hermetic boundary, low historical earthquake occurrence and low earthquake intensity;
preferably, the porosity is not less than 38%.
In certain embodiments, the target geological region should meet the conditions of possessing suitable pore water;
preferably, the water saturation within the target geological region is no less than 30% and no more than 50%; if the ratio exceeds the range, liquid injection or water pumping operation can be performed, so that sufficient pore space is reserved for subsequent liquid injection and carbon injection, and sufficient raw water is reserved for subsequent generation of carbon dioxide hydrate.
As a preferred embodiment, the concentration of the injected 1, 3-dioxolane aqueous solution in the target geological region is not less than 19.5wt%;
preferably, in the gas to be sealed, the purity of the carbon dioxide is more than or equal to 80mol%;
in the technical scheme of the invention, the impurity gas in the gas to be sealed can be any one or more of nitrogen, oxygen and sulfur dioxide.
In yet another aspect, the present invention provides a carbon dioxide sequestration system for operating the above carbon dioxide sequestration method; the carbon dioxide sealing system comprises a monitoring unit, a conveying unit and a hydration reaction unit; the conveying unit is connected with the hydration reaction unit;
the conveying unit comprises a horizontal liquid injection well and a horizontal gas injection well;
the monitoring unit includes a horizontal monitoring well.
In the technical scheme of the invention, the horizontal liquid injection well is used for injecting or extracting liquid from the hydration reaction unit, and the liquid injection comprises injection of 1, 3-dioxolane aqueous solution;
in the technical scheme of the invention, the horizontal gas injection well is used for injecting gas into the hydration reaction unit, and the gas injection comprises injecting gas to be sealed.
Preferably, the horizontal injection well, the horizontal monitoring well and the horizontal gas injection well are distributed from top to bottom in the vertical direction and extend into the hydration reaction unit.
Preferably, the monitoring unit comprises a monitoring device arranged in the horizontal sections of the horizontal injection well, the horizontal monitoring well and the horizontal injection well, and the monitoring device comprises a temperature sensor and a pressure sensor.
Preferably, the storage unit is further included; the storage unit comprises a gas storage unit and a liquid storage unit; the gas storage unit is connected with the input end of the horizontal gas injection well and is used for storing gas to be stored; the liquid storage unit is connected with the input end of the horizontal liquid injection well and is used for storing 1, 3-dioxolane aqueous solution.
Preferably, the power unit is further included; the power unit comprises a gas injection pump and a liquid injection pump; the gas injection pump is connected with the gas storage unit and is used for providing power for the gas storage unit to convey gas to the hydration reaction unit through the horizontal gas injection well; the liquid injection pump is detachably connected with the liquid storage unit and is used for providing power for the liquid storage unit to convey liquid to the hydration reaction unit through the horizontal liquid injection well or providing power for pumping liquid from the hydration reaction unit through the horizontal liquid injection well.
In the technical scheme of the invention, the horizontal monitoring well is used for monitoring the pressure, temperature, porosity, water saturation, resistivity and hydrate saturation in the hydration reaction unit, judging the generation position of the carbon dioxide hydrate according to the evolution of the temperature, the pressure and the resistivity, and providing directional guidance for the subsequent gas injection.
The technical scheme has the following advantages or beneficial effects:
the invention provides a carbon dioxide sealing method and a sealing system, wherein 1, 3-dioxolane is used as an accelerator to participate in carbon dioxide injection and sealing in a large-scale stratum sealing scene. On the one hand, the 1, 3-dioxolane can increase the theoretical storage capacity of the carbon dioxide sealing by a hydrate method and improve the solid-phase sealing capacity of the carbon dioxide. On the other hand, a system of 1, 3-dioxolane, carbon dioxide and water is separated into a 1, 3-dioxolane-rich phase and a water-rich phase under the high-pressure environment of a stratum, and the solubility difference of the two phases of carbon dioxide is large; therefore, the invention can correspondingly adjust carbon dioxide and 1, 3-dioxolane injection and the like according to the conditions of temperature, pressure, water saturation and the like of different stratum, can reduce the diffusion of chemical agents while improving the liquid phase sealing quantity of the carbon dioxide, reduces the environmental influence of using the accelerant, and finally realizes high-efficiency, rapid and environment-friendly CO 2 And (5) geological storage.
Compared with the prior art, the invention has the following advantages:
1. in the sealing scene of a large-scale stratum, the injection of the 1, 3-dioxolane can directly promote CO in the pores 2 Thermodynamic properties of hydrate formation. Second, 1, 3-dioxolane enrichment under formation high pressure inductionThe cyclic phase shows strong CO 2 The dissolution capacity will further increase CO 2 A sequestration amount in the geologic liquid phase. The novel process in the large-scale sealing scene not only can comprehensively promote CO 2 Besides the sealing quantity, the CO can be flexibly adjusted according to the characteristics of different stratum 2 And the injection and sealing scheme of the 1, 3-dioxolane finally realize high-efficiency, quick and environment-friendly CO 2 And (5) geological storage.
The injection of 2.1,3-dioxolane can improve the thermodynamic performance of the generation of the carbon dioxide hydrate, so that the carbon dioxide sealing rate and sealing quantity are increased; the 1, 3-dioxolane has strong carbon dioxide solubility, so that the single gas injection in the engineering operation process can realize larger gas injection amount than the conventional sealing and storing, the gas injection efficiency is improved, and the engineering cost can be reduced; the injected 1, 3-dioxolane can be totally used for carbon dioxide sealing and storage in theory, a part of the injected 1, 3-dioxolane is used as a guest molecule of a carbon dioxide hydrate big cage to assist carbon dioxide absorption, and the 1, 3-dioxolane-rich phase in the residual liquid phase can also be used as a liquid phase sealing and storage carrier with high carbon dioxide solubility, so that the utilization rate of raw materials is extremely high; the residual liquid phase is enriched with 1, 3-dioxolane relative to 1, 3-dioxolane, thereby reducing the concentration of chemical reagents in the residual water, reducing the diffusion of the chemical reagents to the outside of the sealing area and being more beneficial to environmental protection.
3. The addition of the thermodynamic promoter reduces the thermodynamic conditions required for generating the carbon dioxide hydrate, so that the range of sealing and site selection is larger, the limiting conditions are fewer, and the engineering operation is easy.
4. The arrangement of the horizontal well can artificially accelerate the diffusion and seepage of the carbon dioxide in the stratum, and the diffusion and seepage are more fully mixed with stratum water and accelerator solution, so that the conversion rate and the earliest sealing quantity of the carbon dioxide hydrate are improved.
5. The invention expands the application range of the carbon dioxide hydrate method for sealing, can realize the high-efficiency sealing of carbon dioxide in higher-temperature formations such as east China sea, south China sea, and the like and in waste oil gas and natural gas hydrate reservoirs, and has great market value in the fields of carbon sealing, carbon transaction, and the like.
Drawings
Fig. 1 is a schematic structural diagram of a carbon dioxide sequestration system in embodiment 1 of the present invention.
FIG. 2 is a flow chart of the carbon dioxide sequestration process in examples 2-3 of the present invention.
Detailed Description
The following examples are only some, but not all, of the examples of the invention. Accordingly, the detailed description of the embodiments of the invention provided below is not intended to limit the scope of the invention as claimed, but is merely representative of selected embodiments of the invention. All other embodiments, which can be made by a person skilled in the art without making any inventive effort, are intended to fall within the scope of the present invention.
In the present invention, all the equipment, raw materials and the like are commercially available or commonly used in the industry unless otherwise specified. The methods in the following examples are conventional in the art unless otherwise specified.
In the description of the present invention, it should be noted that, if terms such as "center", "upper", "lower", "left", "right", "vertical", "horizontal", "inner", "outer", and the like are used, the indicated orientation or positional relationship is based on the orientation or positional relationship shown in the drawings, only for convenience of describing the present invention and simplifying the description, and does not indicate or imply that the indicated apparatus or element must have a specific orientation, be configured and operated in a specific orientation, and thus should not be construed as limiting the present invention.
In the description of the present invention, it should be noted that unless explicitly stated and limited otherwise, the terms "mounted," "connected," and "connected" should be construed broadly, and may be, for example, fixedly connected, detachably connected, or integrally connected; the two components can be mechanically connected, can be directly connected or can be indirectly connected through an intermediate medium, and can be communicated with each other. The specific meaning of the above terms in the present invention will be understood in specific cases by those of ordinary skill in the art.
Example 1:
as shown in fig. 1, the present embodiment provides a carbon dioxide sequestration system, which includes a monitoring unit, a conveying unit, and a hydration reaction unit 15; the conveying unit is connected with the hydration reaction unit 15; the conveying unit comprises a horizontal liquid injection well 2 and a horizontal gas injection well 1; the monitoring unit comprises a horizontal monitoring well 3.
In this embodiment, the horizontal injection well 2 is provided with an injection well perforation 4 and an injection well packer 5, and the opening/closing of the injection well perforation 4 is controlled by the injection well packer 5 so as to implement the operation of injecting or extracting the hydration reaction unit 15, wherein the injection includes injecting the 1, 3-dioxolane aqueous solution.
In the present embodiment, the horizontal gas injection well 1 is provided with a gas injection well perforation 6 and a gas injection well packer 7, and the gas injection well perforation 6 is controlled to be opened/closed by the gas injection well packer 7 so as to realize gas injection by the hydration reaction unit 15, wherein the gas injection comprises gas injection to be sealed.
Further, the horizontal injection well 2, the horizontal monitoring well 3 and the horizontal section of the horizontal injection well 1 are vertically distributed from top to bottom and extend into the interior of the hydration reaction unit 15. In the technical scheme of the invention, a target geological region (in the embodiment, a region below the seawater 13 is selected as a target sealing region), a region between the lower cladding 16 and the upper cladding 14 is used as a hydration reaction unit 15, a horizontal injection well 2 is laid above the hydration reaction unit 15, a horizontal monitoring well 3 is laid in the middle of the hydration reaction unit, and a horizontal injection well 1 is laid below the hydration reaction unit 15.
Further, the monitoring unit comprises a monitoring device which is arranged in the horizontal sections of the horizontal liquid injection well 2, the horizontal monitoring well 3 and the horizontal gas injection well 1, and the monitoring device comprises a temperature sensor and a pressure sensor.
Further, the device also comprises a storage unit; the storage unit comprises a gas storage unit 8 and a liquid storage unit 10; the gas storage unit 8 is connected with the input end of the horizontal gas injection well 1 and is used for storing gas to be stored; the liquid storage unit 10 is connected with the input end of the horizontal liquid injection well 2 and is used for storing the 1, 3-dioxolane aqueous solution.
Preferably, it also comprises a power unit 9; the power unit 9 comprises a gas injection pump 11 and a liquid injection pump 12; the gas injection pump 11 is connected with the gas storage unit 8 and is used for providing power for the gas storage unit 8 to transmit gas to the hydration reaction unit 15 through the horizontal gas injection well 1; the liquid injection pump 12 is detachably connected to the liquid storage unit 10, and is used for providing power for the liquid storage unit 10 to convey liquid to the hydration reaction unit 15 through the horizontal liquid injection well 2 or providing power for drawing liquid from the hydration reaction unit 15 through the horizontal liquid injection well 2.
In the technical scheme of the invention, the horizontal monitoring well 3 is used for monitoring the pressure, temperature, porosity, water saturation, resistivity and hydrate saturation in the hydration reaction unit 15, judging the generation position of the carbon dioxide hydrate according to the evolution of the temperature, the pressure and the resistivity, and providing directional guidance for the subsequent gas injection.
Example 2:
the actual target geological region selected in this example had an average temperature of 11.0 ℃, an average pressure of 3.0MPa and a water saturation of 25%, and carbon dioxide hydrate could not be produced by carbon dioxide injection without 1, 3-dioxolane injection.
In this embodiment, the carbon dioxide sequestration system in embodiment 1 is used to sequester carbon dioxide in the target geological area, as shown in fig. 2, and the steps are as follows:
after the target geological region is selected, paving corresponding equipment according to the method shown in the figure 1; according to the water saturation lower than 30% measured by the monitoring device, carrying out liquid injection operation through the horizontal liquid injection well 2 until the water saturation is lower than 30%; injecting a 1, 3-dioxolane aqueous solution with the concentration of 39.5wt% into the hydration reaction unit 15 through the horizontal injection well 2, starting the horizontal injection well 2 packer 5, and after the water saturation of the hydration reaction unit 15 is increased to 30%, the average concentration of the 1, 3-dioxolane solution in the hydration reaction unit 15 reaches 19.5wt%; closing a packer 5 of the horizontal liquid injection well 2 to enable the 1, 3-dioxolane solution to uniformly diffuse downwards; then, injecting carbon dioxide gas to be sealed up through the horizontal gas injection well 1, opening a gas injection well packer 7, and gradually reducing the average pressure along with the generation of carbon dioxide hydrate in a target address area after the average pressure in the hydration reaction unit 15 is increased to 4.0 MPa; according to the saturation changes of liquid phase, gas phase and hydrate phase at different positions measured by the monitoring device, aiming at the positions with lower saturation of the hydrate or higher saturation of the liquid phase, opening a packer near the positions, directionally supplementing and injecting carbon dioxide gas, and increasing the generation amount of the carbon dioxide hydrate at the positions; stopping gas injection when the average pressure of the hydration reaction unit 15 is gradually stabilized near 3.0MPa through continuous gas supplementing and generating processes, and closing the horizontal gas injection well 1; the carbon dioxide hydrate sequestration capacity of the hydration reaction cell 15 is now substantially to the top.
In this embodiment, the 1, 3-dioxolane improves the thermodynamic conditions of the hydrates in the sequestration zone 15, so that the carbon dioxide is sequestered in the pores mainly in the form of hydrates, and the remaining 1, 3-dioxolane solution sequesters a small amount of carbon dioxide by dissolution, and the system is not in a significant phase separation state at all.
Example 3:
the actual target geological region selected in this embodiment is: the average temperature is 11.0 ℃, the average pressure is 6.0MPa, the water saturation is 70 percent, and carbon dioxide hydrate can not be generated by injecting carbon dioxide under the condition of not injecting 1, 3-dioxolane.
In this embodiment, the carbon dioxide sequestration system in embodiment 1 is used to sequester carbon dioxide in the target geological area, and the steps are as follows:
after the target geological region is selected, paving corresponding equipment according to the method shown in the figure 1; according to the water saturation measured by the monitoring device being greater than 50%, opening a liquid injection well packer 5, and performing pumping and depressurization operation through the horizontal liquid injection well 2 until the water saturation is reduced to 40%, and reducing the average pressure to 3.0MPa; subsequently, a 1, 3-dioxolane aqueous solution having a concentration of 54.9wt% was injected to increase the water saturation of the hydration reaction unit 15 to 50% and to make the average 1, 3-dioxolane solution concentration of the hydration reaction unit 15 to 19.5wt%; closing the liquid injection well packer 5, and waiting for the 1, 3-dioxolane solution to uniformly diffuse downwards; then injecting carbon dioxide gas through the horizontal gas injection well 1, opening the gas injection well packer 7, closing the gas injection well packer 7 when the average pressure of the hydration reaction unit 15 is increased to 4.0MPa, and then gradually reducing the average pressure of the hydration reaction unit 15 to generate carbon dioxide hydrate. The saturation changes of the liquid phase, the gas phase and the hydrate phase at different positions in the hydration reaction unit 15 are monitored, and for the positions with lower saturation of the hydrate or higher saturation of the liquid phase, the packers near the positions are opened, and the carbon dioxide gas is directionally supplemented and injected, so that the carbon dioxide hydrate generation amount at the positions is increased. The average pressure of the hydration reaction unit 15 was gradually stabilized around 3.0MPa through the continuous air supply and generation process. The carbon dioxide hydrate sequestration capacity of the hydration reaction cell 15 is now substantially to the top. The carbon dioxide gas was then continuously pressurized into the gas injection well 1 up to 6MPa. As shown in FIG. 2, the remaining 1, 3-dioxolane in the hydration unit gradually gathers and is converted into a 1, 3-dioxolane-rich phase having a strong carbon dioxide dissolution capacity, which makes the hydration unit more resistant to carbon dioxide sequestration.
In this embodiment, the 1, 3-dioxolane improves the thermodynamic condition of the hydrate in the hydration reaction unit 15, so that carbon dioxide is mainly stored in the pores in the form of hydrate, and the remaining 1, 3-dioxolane solution is also subjected to phase separation and conversion into a 1, 3-dioxolane-rich phase with strong carbon dioxide dissolution capability, as shown in fig. 2, so that the diffusion of chemical substances is avoided, and the system has a double carbon dioxide storage effect of a hydrate phase and a liquid phase, thereby reducing the waste of raw materials.
The foregoing is only a preferred embodiment of the invention, it being noted that: it will be apparent to those skilled in the art that various modifications and adaptations can be made without departing from the principles of the present invention, and such modifications and adaptations are intended to be comprehended within the scope of the invention.
Claims (10)
1. The carbon dioxide sealing method is characterized by comprising the following steps of:
(1) Injecting an aqueous solution of 1, 3-dioxolane into a target geological region;
(2) And injecting gas to be sequestered into the target geological region, and generating carbon dioxide hydrate through reaction.
2. The method for sequestering carbon dioxide of claim 1, wherein in step (2), after injecting the gas to be sequestered, the difference between the pressure in the target geological region and the initial pressure is less than or equal to 1.0MPa;
preferably, the operation of injecting the gas to be sequestered into the target geological region in step (2) is repeated a plurality of times; specifically, after generating carbon dioxide hydrate through reaction, the pressure in the target geological region is lower than the original stratum pressure by 3.0MPa, and the operation of injecting gas to be sealed into the target geological region is repeated;
preferably, in the step (2), the stage of diffusing the 1, 3-dioxolane aqueous solution is further included before the gas to be sequestered is injected;
preferably, in the last repetition of the operation of injecting the gas to be sequestered into the target geological region, the pressure in the target geological region is maintained for 6-12 months at the initial formation pressure of + -0.5 MPa by adopting a continuous gas injection mode.
3. The carbon dioxide sequestration method of claim 1, further comprising a post-treatment, the post-treatment being a sequestration of the target geological region;
preferably, the target geological region is sealed after the pressure of the target geological region is not lower than the initial pressure and is stable.
4. The carbon dioxide sequestration method of claim 1, wherein the target geological region is an aqueous formation, a subsea formation or an aqueous abandoned hydrocarbon reservoir having suitable thermodynamic conditions for carbon dioxide hydrate formation;
preferably, the maximum temperature within the target geological region does not exceed 15 ℃;
preferably, the initial pressure within the target geological region is not less than 2.5MPa;
preferably, the porosity of the target geological region is greater than or equal to 38%;
preferably, the water saturation within the target geological region is no less than 30% and no more than 50%.
5. The carbon dioxide sequestration process of claim 1, wherein the injected aqueous 1, 3-dioxolane solution has a concentration within the target geological zone of not less than 19.5wt%;
preferably, the purity of the carbon dioxide in the gas to be sealed is more than or equal to 80mol percent.
6. A carbon dioxide sequestration system for operating the carbon dioxide sequestration method of any one of claims 1 to 5, characterized in that it comprises a monitoring unit, a delivery unit, a hydration reaction unit; the conveying unit is connected with the hydration reaction unit;
the conveying unit comprises a horizontal liquid injection well and a horizontal gas injection well;
the monitoring unit includes a horizontal monitoring well.
7. The carbon dioxide sequestration system of claim 6, wherein the horizontal injection well, horizontal monitoring well and horizontal gas injection well horizontal sections are vertically distributed from top to bottom and extend into the interior of the hydration reaction unit.
8. The carbon dioxide sequestration system of claim 6, wherein the monitoring unit comprises a monitoring device disposed within the horizontal sections of the horizontal injection well, horizontal monitoring well and horizontal injection well, the monitoring device comprising a temperature sensor and a pressure sensor.
9. The carbon dioxide sequestration system of claim 6, further comprising a storage unit; the storage unit comprises a gas storage unit and a liquid storage unit; the gas storage unit is connected with the input end of the horizontal gas injection well and is used for storing gas to be stored; the liquid storage unit is connected with the input end of the horizontal liquid injection well and is used for storing 1, 3-dioxolane aqueous solution.
10. The carbon dioxide sequestration system of claim 9, further comprising a power unit; the power unit comprises a gas injection pump and a liquid injection pump; the gas injection pump is connected with the gas storage unit and is used for providing power for the gas storage unit to convey gas to the hydration reaction unit through the horizontal gas injection well; the liquid injection pump is detachably connected with the liquid storage unit and is used for providing power for the liquid storage unit to convey liquid to the hydration reaction unit through the horizontal liquid injection well or providing power for pumping liquid from the hydration reaction unit through the horizontal liquid injection well.
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| Publication number | Priority date | Publication date | Assignee | Title |
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| CN118499677A (en) * | 2024-05-08 | 2024-08-16 | 清华大学深圳国际研究生院 | A method and system for solidifying and storing carbon dioxide on the seabed |
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Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN118499677A (en) * | 2024-05-08 | 2024-08-16 | 清华大学深圳国际研究生院 | A method and system for solidifying and storing carbon dioxide on the seabed |
| CN118499677B (en) * | 2024-05-08 | 2025-03-04 | 清华大学深圳国际研究生院 | Method and system for solidifying and sealing carbon dioxide seabed |
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