CN101190743B - Carbon dioxide geological sequestration method based on mixed fluid self-detaching - Google Patents
Carbon dioxide geological sequestration method based on mixed fluid self-detaching Download PDFInfo
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- CN101190743B CN101190743B CN2007101685523A CN200710168552A CN101190743B CN 101190743 B CN101190743 B CN 101190743B CN 2007101685523 A CN2007101685523 A CN 2007101685523A CN 200710168552 A CN200710168552 A CN 200710168552A CN 101190743 B CN101190743 B CN 101190743B
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- Prior art keywords
- well
- fluid
- mixing
- injection
- drainage well
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/005—Waste disposal systems
- E21B41/0057—Disposal of a fluid by injection into a subterranean formation
- E21B41/0064—Carbon dioxide sequestration
-
- 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
Abstract
The invention discloses a method of carbon dioxide geological sealing based on the self-detaching of mixed fluid and relates to a method of carbon dioxide geological sealing. The invention comprises the following steps: (1) forming an injection well (10) and an emission well (20) in a selected geological sealing site; (2) injecting the mixed fluid containing CO2 continuously by a high pressure injection device into a geological sealing layer (43) through the injection well (10); (3) releasing the fluid moving to the emission well (20) through the emission well (20); (4) injecting the mixed fluid and releasing the emission well (20) continuously until the concentration of CO2 in the fluid discharged by the emission well (20) is larger than the economic concentration value. The invention is suitable for the field of CO2 geological sealing and for sealing CO2 in a deep brine layer, which is especially suitable for the CO2 geological sealing of the deep brine layer of the structure of inclined formation and dome.
Description
Technical field
The present invention relates to a kind of carbon dioxide (CO
2) the geological storage method, relate in particular to a kind of CO based on the fluid-mixing self-separation
2the geological storage method, mainly for CO
2the CO on bittern stratum, deep (dark water stratum)
2geological storage.
Background technology
Current CO
2the place geologic structure type that the geological storage method mainly adopts has: the geologic structures such as oil and natural gas reservoir, bittern stratum, deep (being called for short dark water stratum), the coal seam that can not exploit, basalt.In each type, CO
2geological storage all by CO
2the subsurface rock structure is injected in compression.Current CO
2the method that geological storage adopts has: CO
2-EOR (CO
2the enhancing oil production), CO
2-ECBM (CO
2the enhancing coal bed methane exploring method), CO
2seal up for safekeeping in displacement natural fuels gas field, CO
2seal up for safekeeping in dark water stratum, CO
2basalt is sealed up for safekeeping, CO
2abandoned mine is sealed up for safekeeping, CO
2rock salt is sealed up for safekeeping etc.At present, CO
2geological storage just in three plant-scale projects, carry out (1,000,000 tons of CO
2/ year or above magnitude): Si Laipu Nellie (Sleipner) project in the North Sea; This (Weyburn) project of Canadian Wei and Algerian Sa Lahe (Salah) project.Catch about 3-4 megaton CO every year
2and seal up for safekeeping in geologic structure, otherwise will discharge into the atmosphere.Table 1 has been listed other CO of the whole world
2the geological storage project.Various CO
2the geological storage method is in the stages such as guide, demonstration, industrial scales, and extraordinary effect is arranged.
Above CO
2the geological storage method all needs CO
2catch, transport, inject, the stage such as monitoring forms, CO wherein
2catch cost at whole CO
2the proportion of sealing up for safekeeping in cost is very large, far surpasses half.If can reduce CO
2catch and the cost separated whole CO
2the cost of geological storage can reduce.
Above CO
2the geological storage method adopts the CO that purity is very high entirely
2gas (for example: CO
2concentration>more than 95%) carry out geological storage, therefore to CO
2it is high especially that source of the gas is caught requirement, causes that whole to seal cost up for safekeeping high, and catch cost and be difficult to reduce in a short time, must find the cost that new method reduces geological storage.
The large-scale carbon dioxide geologic sequestration development project that table 1 abroad carries out
Summary of the invention
The above-mentioned shortcoming and defect that the present invention exists in order to overcome prior art, reduce geological storage to source of the gas CO
2the high request of concentration, seal cost up for safekeeping thereby reduce, and improves CO
2the economy of geological storage technology, and a kind of CO based on the fluid-mixing self-separation is provided
2the geological storage method.The present invention is a kind of simple, effectively, and can with conventional CO
2the method that geological storage completes simultaneously.
The object of the present invention is achieved like this.
CO
2the geological storage technology, through development for many years, has become a kind of technology with huge reduction of greenhouse gas discharge potentiality; Various geological storage methods are in guide, demonstration, industry stage, for the proposition of fluid-mixing self-separation carbon dioxide geologic sequestration method is laid a good foundation.
The present invention includes the following step:
1. form Injection Well (10) and drainage well (20) in selected geological storage place, run through cap rock (41) always and enter geological storage layer (43); As shown in Fig. 1 .1.
2. will contain CO by the high pressure injection device
2fluid-mixing continuously by Injection Well (10), inject geological storage layer (43); As shown in Fig. 1 .1.
3. after Injection Well (10) injects certain hour, discharge the fluid that moves to drainage well (20) by drainage well (20), control the pressure of drainage well (20) well head in certain scope simultaneously.
4. continue to carry out the injection of fluid-mixing and the release of drainage well (20), until CO in the fluid that drainage well (20) is discharged
2till concentration is greater than economic concentration value, stop the whole process of sealing up for safekeeping.
Principle of work of the present invention:
The present invention mainly utilizes CO
2solubility in water is far longer than N
2solubility in the brine layer water body and fluid-mixing constantly dissolve two characteristics in transition process.To from source of the gas, catch containing CO
2fluid-mixing, adopt the high pressure injection device by fluid-mixing under certain pressure by Injection Well (10) injection trap structure stratum, deep or seal stratum (43) up for safekeeping; The commitment that fluid-mixing injects, the fluid-mixing of injection mainly arranges the salt solution of water stratum porous medium, occupies the partially porous dielectric space in stratum, and as shown in Fig. 1 .1, the part fluid-mixing is bound in or is dissolved in remaining porous medium hole.Because the density of formation brine is greater than the density of injecting fluid-mixing, fluid-mixing is in the process that arranges and drive formation fluid, fluid-mixing density is less than deep salt solution, fluid-mixing is subject to upwards migration of buoyancy effect, while is due to the low viscosity (LV) (coefficient of viscosity of fluid-mixing far hangs down the coefficient of viscosity with salt solution) of fluid-mixing, fluid-mixing mainly moves along cap rock (41) bottom of top trap layer, fluid-mixing is greater than along the migration velocity of base plate (42) along the speed of cap rock (41) bottom migration, forms the inverted triangle fluid-mixing zone in Fig. 1.The process of moving along the oblique structure stratum especially, fluid-mixing is faster along the speed of cap rock (41) top migration, in the identical time, fluid-mixing, along the longer distance of cap rock (41) migration, forms the inverted triangle fluid-mixing zone (31) in Fig. 1 .2.Various compositions in fluid-mixing constantly dissolve in transition process, and along with the time, the gas componant of the medium and small solubility of fluid-mixing can form the passage be communicated with in cap rock (41) bottom, as shown in Fig. 1 .3.After forming communicating passage, fluid-mixing is constantly with bottom salt solution effect, wherein solvable composition mainly is diffused into low concentration region by forms such as dissolving and molecular diffusion, disperse, density current, convection current, undissolved fluid-mixing composition will collect by the dome (44) in trap structure by communicating passage, by drainage well (20), this part gas is discharged to stratum, seal up for safekeeping like this in stratum and will seal most CO up for safekeeping
2gas, the gas of other little solubility (is mainly N
2) can be discharged well (20) and discharge and to seal up for safekeeping outside stratum (43).
Fluid-mixing arrives near the initial stage of drainage well (20), and also there is no the composition overwhelming majority of constraint and dissolving in fluid-mixing is N
2, few part is CO
2, the fluid composition that drainage well (20) is discharged is mainly N
2, along with the development of injection process, high concentration CO
2can move to drainage well (20) direction, so the CO in drainage well (20)
2concentration can be more and more higher.CO when drainage well (20)
2after concentration surpasses economic concentration, CO
2geological storage can stop, as shown in Figure 3.
The present invention has following advantages and good effect:
The decrease geological storage is to CO
2the concentration requirement of catching, decrease CO
2the cost of catching and whole CO
2the cost of geological storage, increased considerably CO
2the early stage chance of water stratum geological storage.
The present invention is applicable to CO
2the geological storage field, be applicable to CO
2seal up for safekeeping and deep bittern layer (dark water stratum), be particularly suitable for the CO of the deep bittern layer of dipping formation and dome structure
2geological storage; The method is extension and the breakthrough of CO2 geological storage.
The accompanying drawing explanation
Fig. 1 .1 is the schematic diagram that fluid-mixing injects the initial stage;
Fig. 1 .2 is that fluid-mixing forms the communicating passage schematic diagram in sealing stratum up for safekeeping;
Fig. 1 .3 is that fluid-mixing arrives the drainage well schematic diagram;
Fig. 2 is horizontal surface schematic diagram of the present invention;
Fig. 3 is CO in drainage well
2and N
2the concentration changes with time graph of a relation;
Fig. 4 seals up for safekeeping to seal generalized section (multilayer water horizontal well) up for safekeeping under strata condition more;
Fig. 5 is the generalized section of sealing up for safekeeping in the acline situation.
Wherein:
The 10-Injection Well;
11-Injection Well horizontal component;
12-Injection Well vertical component.
The 20-drainage well;
21-drainage well horizontal component;
22-drainage well vertical component.
(formation fluid zone dividing condition)
31-fluid-mixing zone;
32-salt aqua region;
33-fluid-mixing and salt solution boundary zone (mixed zone).
(formation lithology dividing condition)
41-cap rock;
42-base plate (or intermediate course);
43-seals stratum up for safekeeping;
The 44-dome.
The specific embodiment
Below in conjunction with drawings and Examples, the present invention is further described:
This method is to CO
2the innovation of geological storage method, the part technology in orthodox method stands good in the present invention.
1, about place, select and preparation work
The present invention is applicable to the CO on salt solution stratum, general deep
2geological storage, be specially adapted to Trap evaluation structure preferably, the geological storage of fold building or dipping formation condition, the salt solution stratum, deep of sealing up for safekeeping has good cap rock (41) or top board, be generally shale, mud stone, the densifications such as slate, complete continuous, the rock stratum of hyposmosis, require the filtration coefficiont of cap rock (41) penetrablility well below the salt solution water stratum, cap rock (41) has higher air-entry value, and [air-entry value is greater than the mixed-fluid pressure injected by Injection Well (10), at least more than 10MPa], cap rock (41) must be continuously, do not allow to occur strong infiltrative tomography or fracture zone in sealing works scope up for safekeeping.Geological condition for multi-layered aquifer, be strict with the superiors' cap rocks (41) and there is the same character, but middle interlayer [being base plate (42) in Fig. 4] is not needed to so strict standard, the intermediate course gas leakage, can collect at last layer interlayer or cap rock (41) bottom, to whole self-separation CO
2seal impact up for safekeeping little, as shown in Figure 4.
In the water stratum, deep, cap rock (41) preferably has dome (44) (arch structure or other dome shapes structure), form collection region in dome, the fluid of being convenient to collect is concentrated and is discharged by drainage well (20), as shown in Fig. 1 .3, for multi-layered aquifer, same requirement is arranged.If, without the dome structure, drainage well (20) position can adopt the form in Fig. 5, but the drainage well (20) of the relative dome structure of emissions operation difficulty is larger.
2, about step 1.
As shown in Fig. 1 .1～1.3, geological storage of the present invention place is deep bittern layer, at least comprises an Injection Well (10) and a drainage well (20).The form of Injection Well (10) and drainage well (20) is various, can adopt the various forms of drilling wells such as horizontal drainhole, perpendicular hole.
Deposit the structure place in selected feud matter and form Injection Well (10) and drainage well (20), run through cap rock (41) always and enter geological storage layer (43);
Injection Well (10) and drainage well (20) generally adopt horizontal well technology Cheng Jing, and horizontal drainhole comprises: the horizontal well technology such as ultra-long horizontal well, small curve horizontal drainhole, vertical water horizontal well, multi-branched horizontal well, pinniform horizontal drainhole.The technology of horizontal drainhole is very ripe, can directly adopt.The vertical component of Injection Well (10) and drainage well (20) enters trap structure inside through cap rock (41).Need abundant sealing between the vertical well casing through the cap rock of drilling well and cap rock (41), prevent that fluid-mixing from escaping out and sealing stratum (43) up for safekeeping by the weak seal link.The horizontal component of drilling well is parallel to course of seam as far as possible, realizes more sequestration of carbon dioxide on large tracts of land.
In work progress, the horizontal component of Injection Well (11) is positioned at as far as possible seals bottom, stratum (43) up for safekeeping; And the horizontal component of drainage well (21) is positioned at the top of sealing stratum (43) up for safekeeping as far as possible, be convenient to discharge the fluid that collects in dome.
The position of Injection Well (10) and drainage well (20) depends primarily on stratigraphic structure, drainage well (20) generally is positioned at dome (44) position, mainly be convenient to the migration of fluid and collect, (spacing that horizontal drainhole is horizontal segment) spacing of Injection Well (10) and drainage well (20) is generally 50～100km, and optimal spacing is 1km～10km scope.
Injecting fluid-mixing early stage and initial stage, can suitably reduce the whole fluid pressure of sealing stratum up for safekeeping by modes such as Injection Well (10) and drainage well (20) pump drainage or hold-off pressures, then can reduce the injection difficulty of fluid-mixing, improving injection.Become in the well process to pay particular attention to sealing problem between sleeve pipe withstand voltage and drilling well and rock stratum.
3, about step 2.:
By the high pressure injection device, by fluid-mixing, (main component is CO
2, N
2, all the other compositions are not limit, and all the other component contents are a small amount of and trace) by Injection Well (10), inject and seal stratum (43) up for safekeeping continuously; Pressure in Injection Well need to be greater than the pressure of formation fluid.
Inject fluid-mixing CO
2concentration is more high better, and concentration is higher, the CO that seal up for safekeeping in place
2also more, free air capacity is also fewer, the corresponding minimizing of injection rate; But CO
2catching cost can be higher, so the necessary balance of between and compromise, CO
2between concentration preferably can be greater than 60%～90% (existing low-cost gas separation be easy to reach or some source of gaseous emission in itself meet these requirements), thereby realize that whole sealing up for safekeeping in process catch and the lowest cost injected.
4, about step 3.
After injecting certain hour, near fluid drainage well (20) release moves to drainage well (20), need the pressure of controlling drainage well (20) well head in certain scope, the CO in the Real-Time Monitoring Exhaust Gas in discharge process
2concentration, and control drainage well (20) surface pressure, do not allow (controlling the drainage well surface pressure), CO
2dividing potential drop too low, cause around drainage well being dissolved in CO in salt solution
2gas evolution enters drainage well (20).
Certain hour described above does not clearly define, and depends primarily on the time that fluid-mixing moves to drainage well (20) and collects bottom dome (44) or cap rock (41).Generally according to monitoring information, determine.
5, about step 4.
Continue to carry out step 2. 3., realize following purpose.
Along with the carrying out of injection process and exhaust process, the composition that drainage well (20) is discharged in fluid-mixing changes as shown in Figure 2; About the determined value of economic concentration, the present invention does not comprise this value, by specific operation process, is determined, general CO
2the scope of concentration is 30%～60%, optimized CO
2economic concentration is determined by concrete engineering.Gas concentration lwevel surpasses this value, stops fluid-mixing at once and injects, and the whole work of sealing up for safekeeping completes.
Claims (1)
1. the carbon dioxide geologic sequestration method based on the fluid-mixing self-separation, is characterized in that comprising the following steps:
1. form Injection Well (10) and drainage well (20) in selected geological storage place, run through cap rock (41) always and enter geological storage layer (43);
2. will contain CO by the high pressure injection device
2fluid-mixing continuously by Injection Well (10), inject geological storage layer (43);
In fluid-mixing, gas concentration lwevel is between 60%～90%;
3. after Injection Well (10) injects certain hour, discharge the fluid that moves to drainage well (20) by drainage well (20), control the pressure of drainage well (20) well head in certain scope simultaneously;
4. continue to carry out the injection of fluid-mixing and the release of drainage well (20), until CO in the fluid that drainage well (20) is discharged
2till concentration is greater than economic concentration value, stop the whole process of sealing up for safekeeping;
Described geological storage place is deep bittern layer, seals place up for safekeeping and at least comprises an Injection Well (10) and a drainage well (20).
Priority Applications (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN2007101685523A CN101190743B (en) | 2007-11-30 | 2007-11-30 | Carbon dioxide geological sequestration method based on mixed fluid self-detaching |
| PCT/CN2008/072608 WO2009071001A1 (en) | 2007-11-30 | 2008-10-07 | A carbon dioxide underground storage method based on fluid mixture self-separation |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN2007101685523A CN101190743B (en) | 2007-11-30 | 2007-11-30 | Carbon dioxide geological sequestration method based on mixed fluid self-detaching |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN101190743A CN101190743A (en) | 2008-06-04 |
| CN101190743B true CN101190743B (en) | 2013-11-06 |
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| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN2007101685523A Expired - Fee Related CN101190743B (en) | 2007-11-30 | 2007-11-30 | Carbon dioxide geological sequestration method based on mixed fluid self-detaching |
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| Country | Link |
|---|---|
| CN (1) | CN101190743B (en) |
| WO (1) | WO2009071001A1 (en) |
Families Citing this family (18)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101190743B (en) * | 2007-11-30 | 2013-11-06 | 中国科学院武汉岩土力学研究所 | Carbon dioxide geological sequestration method based on mixed fluid self-detaching |
| US7726402B2 (en) * | 2008-07-03 | 2010-06-01 | Schlumberger Technology Corporation | Methods for downhole sequestration of carbon dioxide |
| JP2012519587A (en) * | 2009-03-11 | 2012-08-30 | モーリス・ビー・デュソウルト | Method for isolating fluid in the formation |
| EP2465603B1 (en) * | 2009-08-12 | 2019-10-30 | Tokyo Gas Co., Ltd. | Device and method for sequestering a substance |
| NO333942B1 (en) * | 2010-07-01 | 2013-10-28 | Statoil Petroleum As | Methods for storing carbon dioxide compositions in geological subsurface formations and devices for use in such processes |
| CN102207243B (en) * | 2011-05-06 | 2013-05-15 | 四川大学 | Method and device for building underground storage by dissolving limestone with carbon dioxide |
| US9586759B2 (en) | 2011-06-30 | 2017-03-07 | Statoil Petroleum As | Method for storing carbon dioxide compositions in subterranean geological formations and an arrangement for use in such methods |
| CN102519679A (en) * | 2011-12-26 | 2012-06-27 | 中国科学院地质与地球物理研究所 | Method for measuring leakage caused by drilling in geological storage process of CO2 |
| CN102942006B (en) * | 2012-11-29 | 2015-12-02 | 河南理工大学 | The method of sequestration of carbon dioxide |
| WO2014089185A1 (en) * | 2012-12-06 | 2014-06-12 | Cornell University | Extraction-injection method for immobilized sub-surface geologic storage of carbon dioxide |
| CN104675360B (en) * | 2014-12-22 | 2017-03-29 | 中国石油大学(华东) | Note supercritical CO2The pre- antiseep technique of exploitation dry-hot-rock geothermal |
| CN104850742B (en) * | 2015-05-08 | 2017-11-21 | 河北工程大学 | A kind of method that calculating CO2 salt water layer mineral seal potentiality up for safekeeping |
| CN106498920A (en) * | 2016-10-26 | 2017-03-15 | 中国地质大学（北京） | The method for numerical simulation of seepage flow Changing Pattern during a kind of wide open digging of oil storage |
| CN111219186B (en) * | 2020-01-14 | 2023-03-21 | 国网湖南省电力有限公司 | Method for storing compressed gas energy by utilizing deep aquifer |
| KR102605955B1 (en) * | 2021-11-08 | 2023-11-24 | 한국석유공사 | Method for selecting location of injection well for co2 geological storage and injection method using the same |
| CN115059445A (en) * | 2022-06-13 | 2022-09-16 | 成都理工大学 | Method and system for geological sequestration of carbon dioxide in depleted reservoirs |
| CN115492557B (en) * | 2022-10-18 | 2023-11-07 | 中国矿业大学 | Deep non-recoverable coal seam CO 2 Sealing and storing device and method for extracting coalbed methane under negative pressure |
| CN116658137B (en) * | 2023-07-21 | 2023-10-31 | 中国石油大学(华东) | Method and system for sealing and self-flowing water injection of aquifer CO ₂ to increase yield of crude oil |
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| JP3908780B1 (en) * | 2006-09-27 | 2007-04-25 | 石油資源開発株式会社 | Water-soluble natural gas recovery method using carbon dioxide-dissolved water |
| CN101190743B (en) * | 2007-11-30 | 2013-11-06 | 中国科学院武汉岩土力学研究所 | Carbon dioxide geological sequestration method based on mixed fluid self-detaching |
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- 2007-11-30 CN CN2007101685523A patent/CN101190743B/en not_active Expired - Fee Related
-
2008
- 2008-10-07 WO PCT/CN2008/072608 patent/WO2009071001A1/en active Application Filing
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|---|---|
| CN101190743A (en) | 2008-06-04 |
| WO2009071001A1 (en) | 2009-06-11 |
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