CN108915643B - Dual communication well structure and method for exploiting ocean hydrates - Google Patents
Dual communication well structure and method for exploiting ocean hydrates Download PDFInfo
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- CN108915643B CN108915643B CN201810716966.3A CN201810716966A CN108915643B CN 108915643 B CN108915643 B CN 108915643B CN 201810716966 A CN201810716966 A CN 201810716966A CN 108915643 B CN108915643 B CN 108915643B
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—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
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/17—Interconnecting two or more wells by fracturing or otherwise attacking the formation
Abstract
The invention relates to the field of energy exploitation, and discloses a double-communication-well structure and a method for exploiting a marine hydrate. In addition, the invention can further improve the exploitation efficiency of the natural gas hydrate and maintain the stability of the reservoir stratum by injecting carbon dioxide into the hydrate layer and combining the heat injection method and the displacement method.
Description
Technical Field
The invention relates to the technical field of energy exploitation, in particular to a double-communication-well structure and a method for exploiting ocean hydrates.
Background
Since the industrial revolution, the global energy demand has been continuously increased, and in recent years, as conventional petroleum resources have been reduced and the energy problem has become more severe, various countries have begun to turn their eyes to unconventional energy. Among them, natural gas hydrate resources are particularly receiving attention. Natural gas hydrate, also called as combustible ice, is a novel energy source with abundant reserves and relatively clean. It is primarily produced by combining natural gas with water at a sufficiently low temperature and a sufficiently high pressure. According to research for many years, the natural gas hydrate originally in nature is mainly distributed in polar permafrost zones in high-latitude areas and deep sea floors, land slopes, land bases and sea ditches in the world, and the extreme reservoir environment makes it difficult to recover the natural gas hydrate in the ocean. Generally, the hydrate is first decomposed and then the free natural gas is collected.
At present, methods for exploiting natural gas hydrates can be classified into a heat injection method, a depressurization method, a chemical agent method, and a carbon dioxide displacement method. The heat injection method is characterized in that a hot fluid with a certain temperature is injected into a natural gas hydrate reservoir stratum in the sea on the ground by using an electric pump, or a fire flooding and other underground heating methods are adopted to increase the system temperature in the reservoir stratum and promote the decomposition of the natural gas hydrate; the depressurization method is to change the phase balance of the hydrate to a certain extent by reducing the pressure of a reservoir system so as to promote the natural gas hydrate to be decomposed; the chemical agent method is to inject methanol chemical agent to promote the decomposition of natural gas hydrate; the carbon dioxide displacement method is to inject carbon dioxide with certain pressure and temperature into a reservoir from the ground to displace methane in the natural gas hydrate so as to promote the decomposition of the natural gas hydrate.
Although the four methods can realize the exploitation of the natural gas hydrate, the low heat transfer efficiency and the flow conductivity of the hydrate reservoir are still two problems of the exploitation of the natural gas hydrate. Therefore, how to improve the heat transfer efficiency and the flow conductivity of the reservoir so as to improve the exploitation efficiency of the natural gas hydrate and save the cost is a hot problem of global attention at present.
Disclosure of Invention
The invention aims to provide a double-communication-well structure and a double-communication-well method for exploiting an ocean hydrate, so that the heat transfer efficiency and the flow conductivity of a reservoir are improved, and the efficient exploitation of a natural gas hydrate is realized.
In order to achieve the above objects, the present invention provides, in one aspect, a dual communication well structure for the production of marine hydrates, the dual communication well structure comprising a first injection well extending from a sea level to a hydrate layer for the injection of carbon dioxide, a second injection well for the injection of a thermal fluid or a hydrate decomposition promoter, and a production well for the recovery of decomposition products of the hydrate layer;
the dual communication well structure further comprises a first communication well and a second communication well located in the hydrate layer, the first communication well being spaced below the second communication well, wherein: an inlet end of the first communication well is communicated with an outlet end of the first injection well, an outlet end of the first communication well is communicated with an inlet end of the production well, and the first communication well is used for injecting the carbon dioxide upwards into the hydrate layer and collecting decomposition products of the hydrate layer; the inlet end of the second communicating well is communicated with the outlet end of the second injection well, the outlet end of the second communicating well is communicated with the inlet end of the production well, and the second communicating well is used for injecting the hot fluid or hydrate decomposition accelerator downwards into the hydrate layer and collecting decomposition products of the hydrate layer at the same time.
Preferably, the first communication well and the second communication well are both formed as a horizontal well.
Preferably, the central axis of the second communication well is located 1/6-1/8 from the top surface of the hydrate layer and the central axis of the first communication well is located 1/6-1/8 from the bottom surface of the hydrate layer.
Preferably, the first communicating well and the second communicating well are both screen pipes; or
A plurality of first openings are formed in the top wall of the first communication well and are arranged at intervals along the extending direction of the first communication well; a plurality of second openings are formed in the bottom wall of the second communicating well and are arranged at intervals along the extending direction of the second communicating well.
Preferably, the dual communication well structure includes a pressurisation device for increasing the pressure of fluid entering the first communication well.
Preferably, the pressurising means is located at an outlet end of the first injection well or an inlet end of the first communication well, the pressurising means being arranged to block direct communication between the first injection well and the first communication well, the pressurising means comprising a nozzle in the shape of a shower, the inlet of the nozzle communicating with the first injection well and the outlet of the nozzle communicating with the first communication well.
In another aspect, the present invention provides a method for producing marine hydrates, the method comprising:
s1, simultaneously injecting hot fluid or hydrate decomposition promoter and carbon dioxide into the hydrate layer from two different heights of the hydrate layer along opposite directions to form a flow channel in the hydrate layer;
s2, collecting the decomposition products of the hydrate layer from the two different heights.
Preferably, the S1 includes: 300 to 400m3Injecting the thermal fluid or hydrate decomposition accelerator with the temperature of 80-90 ℃ at the speed of one day, wherein the injection speed is 200-300 m3Injecting the carbon dioxide at a rate of 60 ℃ to 90 ℃ per day; and/or
The hydrate decomposition accelerator adopts saline water with the mass concentration of 5-25%.
Preferably, the method comprises: adjusting the injection amounts of the thermal fluid or hydrate decomposition promoter and the carbon dioxide, respectively, at a rate reduced by 2% to 5% per day when the production amount of the decomposition product is stable.
Preferably, the method employs the dual communication well configuration described above.
According to the double-communication-well structure, the two communication wells which are arranged at intervals up and down are arranged on the hydrate layer, so that pressure difference can be formed between the two communication wells, a corresponding flow channel can be formed in the hydrate layer under the action of the pressure difference, the flow of injected fluid and fluid in the hydrate layer is facilitated, the contact area between the injected fluid and the hydrate layer is increased, the flow of the fluid can drive heat exchange, the heat transfer efficiency and the flow guide capacity of the hydrate layer can be improved, and the exploitation efficiency of natural gas hydrate is improved. In addition, the invention can further improve the exploitation efficiency of the natural gas hydrate and maintain the stability of the reservoir stratum by injecting carbon dioxide into the hydrate layer and combining the heat injection method and the displacement method.
Additional features and advantages of the invention will be set forth in the detailed description which follows.
Drawings
The accompanying drawings, which are included to provide a further understanding of the invention and are incorporated in and constitute a part of this specification, illustrate embodiments of the invention and together with the description serve to explain the principles of the invention and not to limit the invention. In the drawings:
FIG. 1 is a schematic diagram of one embodiment of a dual communication well configuration of the present invention;
fig. 2 is a schematic structural view of an embodiment of the supercharging apparatus according to the present invention.
Description of the reference numerals
10 first injection well 101 first injection well wellhead
11 second injection well 111 second injection well wellhead
12 production well 121 production well head
13 first communication well 14 second communication well
15 supercharging device 151 nozzle
152 housing 153 seal
20 sea level 21 hydrate layer
22 cap layer 23 formation
Detailed Description
The following detailed description of embodiments of the invention refers to the accompanying drawings. It should be understood that the detailed description and specific examples, while indicating the present invention, are given by way of illustration and explanation only, not limitation.
In the present invention, unless otherwise specified, the terms of orientation such as "up and down" used generally refer to up and down in the mounted and used state. "inner and outer" refer to the inner and outer contours of the respective component itself.
In the present invention, the internal structure of the ocean is simply divided into the sea level 20, the sea water layer, the cover layer 22, the hydrate layer 21 and the stratum 23, which are distributed from top to bottom in this order, for the convenience of understanding.
In one aspect, the present invention provides a dual communication well structure for the production of marine hydrates, comprising a first injection well 10 extending from sea level 20 to a hydrate layer 21, a second injection well 11 and a production well 12, wherein the first injection well 10 is used for the injection of carbon dioxide, the second injection well 11 is used for the injection of a thermal fluid or a hydrate decomposition promoter, and the production well 12 is used for the recovery of the decomposition products of the hydrate layer 21; the double communication well structure further comprises a first communication well 13 and a second communication well 14 located in the hydrate layer 21, the first communication well 13 being located at a distance below the second communication well 14, wherein: an inlet end of the first communication well 13 is communicated with an outlet end of the first injection well 10, an outlet end of the first communication well 13 is communicated with an inlet end of the production well 12, and the first communication well 13 is used for injecting the carbon dioxide upwards into the hydrate layer 21 and collecting decomposition products of the hydrate layer 21; the inlet end of the second communicating well 14 is communicated with the outlet end of the second injection well 11, the outlet end of the second communicating well 14 is communicated with the inlet end of the production well 12, and the second communicating well 14 is used for injecting the hot fluid or hydrate decomposition accelerator downwards into the hydrate layer 21 and collecting the decomposition products of the hydrate layer 21.
That is, carbon dioxide injected from the first injection well 10 may be released into the hydrate layer 21 through the first communication well 13, hot fluid or hydrate decomposition promoter injected from the second injection well 11 may be released into the hydrate layer 21 through the second communication well 14, and decomposition products in the hydrate layer 21 may be collected through the first communication well 13 and the second communication well 14 into the production well 12 for recovery.
According to the double-communication-well structure, the hydrate layer 21 is provided with the two communication wells (namely the first communication well 13 and the second communication well 14) which are arranged at intervals up and down, and the first communication well 13 and the second communication well 14 are positioned at different heights of the hydrate layer 21, so that a pressure difference can be formed between the first communication well 13 and the second communication well 14, and under the action of the pressure difference, a corresponding flow channel can be formed in the hydrate layer 21 (namely in an area between the first communication well 13 and the second communication well 14), so that the flow of the injected fluid and the fluid in the hydrate layer is facilitated, the contact area between the injected fluid and the hydrate layer is increased, the flow of the fluid can drive the heat exchange, the heat transfer efficiency and the flow guide capability of the hydrate layer can be improved, and the exploitation efficiency of natural gas hydrate can be improved. In addition, the invention can further improve the exploitation efficiency of the natural gas hydrate and maintain the stability of the reservoir stratum by injecting carbon dioxide into the hydrate layer and combining the heat injection method and the displacement method.
As shown in fig. 1, the first communicating well 13 is vertically located below the second communicating well 14, and according to the principle that the hot fluid with a relatively high density flows downwards and the gas with a relatively low density flows upwards, the upward flow of carbon dioxide is facilitated, and the downward flow of the hot fluid or the hydrate decomposition promoter accelerates the formation of a flow channel and the action of the injected fluid and the hydrate layer.
In the present invention, both the first communication well 13 and the second communication well 14 may be formed as horizontal wells. In this way, the first communicating well 13 and the second communicating well 14 can release energy by means of heat conduction and convection heat transfer, hydrate decomposition is promoted, and decomposition products are collected at the same time. In addition, the well completion period can be shortened, the well drilling cost is reduced, and the exploitation time is saved.
In addition, the first injection well 10, the second injection well 11 and the production well 12 also have a first injection well head 101, a second injection well head 111 and a production well head 121, respectively, to facilitate injection of fluids and recovery of decomposition products. Furthermore, the first injection well 10, the second injection well 11 and the production well 12 are preferably formed as vertical wells, and it should be noted here that the first injection well 10, the second injection well 11 and the production well 12 may include not only vertical sections, but also horizontal sections, respectively, for example, as shown in fig. 1, in order to facilitate drilling, well-to-well communication and practical effects.
Further, preferably, the central axis of the second communication well 14 is located 1/6-1/8 from the top surface of the hydrate layer 21, and the central axis of the first communication well 13 is located 1/6-1/8 from the bottom surface of the hydrate layer 21. Through the arrangement, the area between the first communicating well 13 and the second communicating well 14 can be maximized, natural gas hydrate can be exploited to the maximum extent, and meanwhile, the effective collection of decomposition products is guaranteed. In addition, 1/6-1/8 refers to the height of 1/6-1/8 of hydrate layer 21.
Furthermore, according to an embodiment of the present invention, the first communication well 13 and the second communication well 14 may be each a screen. It will be appreciated that the screen wall has a plurality of through holes disposed therein through which fluid can pass from and to the inside of the pipe (see figure 1). By adopting the sieve tube, the heat conduction and convection heat transfer of fluid inside and outside the tube can be enhanced, the heat transfer effect is enhanced, and local low pressure can be generated in the sieve tube at a certain flow rate, so that the decomposition products in the hydrate layer 21 can enter the sieve tube. In this case, the injection fluid may be discharged from the peripheries of the first communication well 13 and the second communication well 14, respectively, and the decomposition products may be introduced into the first communication well 13 and the second communication well 14 from the peripheries of the first communication well 13 and the second communication well 14, respectively, when the decomposition products are collected. That is, in addition to the region between the first communication well 13 and the second communication well 14, the first communication well 13 and the second communication well 14 may inject fluid into the hydrate layer 21 from other directions to promote decomposition of natural gas hydrate in other regions of the hydrate layer 21.
According to another embodiment of the present invention, a plurality of first openings are formed in a top wall of the first communication well 13, and the plurality of first openings are arranged at intervals along an extending direction of the first communication well 13; a plurality of second openings are formed in the bottom wall of the second communicating well 14, and are arranged at intervals along the extending direction of the second communicating well 14. In this case, the first communication well 13 and the second communication well 14 can inject fluid only to the region of the hydrate layer 21 between the first communication well 13 and the second communication well 14.
In the present invention, the double well structure may further include a pressurizing means 15 for increasing the pressure of the fluid introduced into the first well 13, which may facilitate the formation of a flow channel.
According to an embodiment of the present invention, the pressurizing device 15 may be disposed at an outlet end of the first injection well 10 or an inlet end of the first communication well 13, the pressurizing device 15 is disposed to block direct communication between the first injection well 10 and the first communication well 13, the pressurizing device 15 includes a nozzle 151 having a shower shape, an inlet of the nozzle 151 is communicated with the first injection well 10, and a nozzle opening of the nozzle 151 is communicated with the first communication well 13. Specifically, as shown in fig. 2, a cylindrical cavity and a truncated cone cavity with an inner diameter gradually increasing and extending outward from one end of the cylindrical cavity are defined inside the nozzle 151, the cylindrical cavity and the truncated cone cavity are coaxially arranged, an inlet of the nozzle 151 is formed at one end of the cylindrical cavity (i.e., the left end in fig. 2) far away from the truncated cone cavity, and a plurality of nozzles are formed at one end of the truncated cone cavity (i.e., the right end in fig. 2) far away from the cylindrical cavity. In addition, in order to protect the nozzle 151 and block the direct communication between the first injection well 10 and the first communication well 13, the pressure boosting device 15 may further include a housing 152 sleeved outside the nozzle 151 and a sealing member 153 disposed outside the housing 152, wherein the sealing member 153 is configured to be in sealing fit with an inner wall of the first injection well 10 or the first communication well 13. That is, fluid from the first injection well 10 can only enter the cylindrical cavity from the entrance of the nozzle 151, which, because of its smaller diameter than the inner diameter of the first injection well 10, increases the fluid flow rate, creating a local low pressure there to facilitate hydrate dissociation; and the fluid forms bubble flow when passing through the nozzle, and is easier to contact with the hydrate layer 21, thereby facilitating the production.
In another aspect, the present invention provides a method for producing marine hydrates, the method comprising:
s1, simultaneously injecting hot fluid or hydrate decomposition accelerator and carbon dioxide into the hydrate layer 21 in opposite directions from two different heights of the hydrate layer 21, respectively, to form a flow channel in the hydrate layer 21;
s2, collecting the decomposition products of the hydrate layer 21 from the two different heights.
According to the method, the hot fluid or the hydrate decomposition promoter and the carbon dioxide are injected into the hydrate layer 21 from two different heights of the hydrate layer 21 along opposite directions, so that a flow channel can be formed in the hydrate layer 21, the heat transfer efficiency and the flow conductivity of the hydrate layer can be improved, and the exploitation efficiency of the natural gas hydrate is improved; by collecting the decomposition products of the hydrate layer 21 from the two different heights, it is possible to reduce the extraction cost of the hydrate while effectively collecting the decomposition products. It should be noted that the effect achieved by the above method of the present invention can be specifically explained by referring to the description in the above dual communication well structure.
Preferably, S1 includes: 300 to 400m3Injecting the thermal fluid or hydrate decomposition accelerator with the temperature of 80-90 ℃ at the speed of one day, wherein the injection speed is 200-300 m3The carbon dioxide is injected at a rate of 60 ℃ to 90 ℃ per day. The carbon dioxide is easier to replace with the natural gas hydrate under the high-temperature condition, the high-temperature heat dissipation of the fluid is beneficial to improving the lower heat transfer efficiency of the hydrate reservoir, the decomposition of the hydrate is promoted, meanwhile, the pressure of the carbon dioxide is reduced along with the continuous transmission of heat, the phase state balance of the hydrate is changed, and the exploitation efficiency of the hydrate reservoir is improved.
In addition, the hydrate decomposition accelerator preferably adopts brine with the mass concentration of 5-25%.
In the exploitation process, at the initial stage of injection, the capacity of carbon dioxide for replacing methane under a high-temperature condition is strong, the pressure is reduced due to the reduction of the temperature while heat is transferred, meanwhile, under the multiple excitation of fluid injected into the upper and lower communicating wells to emit heat energy or hydrate decomposition accelerator, the natural gas hydrate starts to decompose, gas generated by decomposition enters the communicating wells under the action of the pressure difference of the upper and lower communicating wells, and meanwhile, a flow channel is formed in the hydrate layer 21; after a period of mining, along with the continuous decomposition of the hydrate, the contact area between the hydrate layer 21 and the injected fluid is continuously increased, so that the heat and mass transfer efficiency of the hydrate layer 21 is effectively improved; after the exploitation is carried out for a period of time, the contact area between the hydrate layer 21 and the injected fluid gradually tends to be stable, when the yield of decomposition products in the hydrate layer 21 tends to be stable, the injection amount of the hot fluid or hydrate decomposition accelerator and the carbon dioxide is respectively adjusted at a rate of reducing 2% -5% every day, the daily gas yield is controlled in the process, the proportion of gas in the fluid is relatively increased due to the fact that the amount of the injected fluid in the shaft is continuously reduced, the pressure is continuously reduced, the depressurization exploitation is further achieved, the exploitation efficiency of the hydrate is improved, and the exploitation stability is guaranteed.
In the invention, the method can adopt the double-communication-well structure, and of course, any other structure or device capable of realizing the method can be adopted.
The preferred embodiments of the present invention have been described in detail with reference to the accompanying drawings, however, the present invention is not limited to the specific details of the above embodiments, and various simple modifications can be made to the technical solution of the present invention within the technical idea of the present invention, and these simple modifications are within the protective scope of the present invention.
It should be noted that the various features described in the above embodiments may be combined in any suitable manner without departing from the scope of the invention. The invention is not described in detail in order to avoid unnecessary repetition.
In addition, any combination of the various embodiments of the present invention is also possible, and the same should be considered as the disclosure of the present invention as long as it does not depart from the spirit of the present invention.
Claims (9)
1. A dual communication well structure for the exploitation of marine hydrates,
the dual communication well structure comprises a first injection well (10) extending from sea level (20) to a hydrate layer (21), a second injection well (11) and a production well (12), wherein the first injection well (10) is used for injecting carbon dioxide, the second injection well (11) is used for injecting hot fluid or hydrate decomposition accelerator, and the production well (12) is used for recovering decomposition products of the hydrate layer (21);
the dual communication well structure further comprises a first communication well (13) and a second communication well (14) located in the hydrate layer (21), the first communication well (13) being spaced below the second communication well (14), wherein: the inlet end of the first communication well (13) is communicated with the outlet end of the first injection well (10), the outlet end of the first communication well (13) is communicated with the inlet end of the production well (12), and the first communication well (13) is used for injecting the carbon dioxide upwards into the hydrate layer (21) and collecting the decomposition products of the hydrate layer (21); the inlet end of the second communication well (14) is communicated with the outlet end of the second injection well (11), the outlet end of the second communication well (14) is communicated with the inlet end of the production well (12), and the second communication well (14) is used for injecting the hot fluid or hydrate decomposition accelerator downwards into the hydrate layer (21) and collecting the decomposition products of the hydrate layer (21).
2. The double communication well structure according to claim 1, characterized in that said first communication well (13) and said second communication well (14) are both formed as horizontal wells.
3. The dual communication well structure of claim 2, wherein the central axis of the second communication well (14) is located 1/6-1/8 from the top surface of the hydrate layer (21), and the central axis of the first communication well (13) is located 1/6-1/8 from the bottom surface of the hydrate layer (21).
4. The double communication well structure according to claim 2, characterized in that said first communication well (13) and said second communication well (14) are each screened; or
A plurality of first openings are formed in the top wall of the first communication well (13), and are arranged at intervals along the extending direction of the first communication well (13); a plurality of second openings are formed in the bottom wall of the second communicating well (14), and are arranged at intervals along the extending direction of the second communicating well (14).
5. The twin well structure according to any one of claims 1 to 4, characterised in that it comprises pressurising means (15) for increasing the pressure of fluid entering the first well (13).
6. The double well structure according to claim 5, characterized in that said pressurization means (15) are located at the outlet end of said first injection well (10) or at the inlet end of said first communication well (13), said pressurization means (15) being arranged to block the direct communication of said first injection well (10) and said first communication well (13), said pressurization means (15) comprising a nozzle (151) in the shape of a shower, the inlet of said nozzle (151) being in communication with said first injection well (10), the outlet of said nozzle (151) being in communication with said first communication well (13).
7. A method for producing marine hydrates using the dual communication well structure of any one of claims 1 to 6, the method comprising:
s1, simultaneously injecting hot fluid or hydrate decomposition promoting agent and carbon dioxide into the hydrate layer (21) along opposite directions from two different heights of the hydrate layer (21) respectively to form a flow channel in the hydrate layer (21);
s2, collecting the decomposition products of the hydrate layer (21) from the two different heights.
8. The method according to claim 7, wherein the S1 includes: 300 to 400m3Injecting the thermal fluid or hydrate decomposition accelerator with the temperature of 80-90 ℃ at the speed of one day, wherein the injection speed is 200-300 m3Injecting the carbon dioxide at a rate of 60 ℃ to 90 ℃ per day; and/or
The hydrate decomposition accelerator adopts saline water with the mass concentration of 5-25%.
9. The method of claim 8, wherein the method comprises: adjusting the injection amounts of the thermal fluid or hydrate decomposition promoter and the carbon dioxide, respectively, at a rate reduced by 2% to 5% per day when the production amount of the decomposition product is stable.
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| CN111271035B (en) * | 2020-02-13 | 2021-10-26 | 中国石油大学(华东) | Natural gas hydrate exploitation well structure |
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