CN115370324A - Natural gas hydrate heat injection exploitation system and method - Google Patents
Natural gas hydrate heat injection exploitation system and method Download PDFInfo
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- CN115370324A CN115370324A CN202110550069.1A CN202110550069A CN115370324A CN 115370324 A CN115370324 A CN 115370324A CN 202110550069 A CN202110550069 A CN 202110550069A CN 115370324 A CN115370324 A CN 115370324A
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- natural gas
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- 238000002347 injection Methods 0.000 title claims abstract description 105
- 239000007924 injection Substances 0.000 title claims abstract description 105
- NMJORVOYSJLJGU-UHFFFAOYSA-N methane clathrate Chemical compound C.C.C.C.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O NMJORVOYSJLJGU-UHFFFAOYSA-N 0.000 title claims abstract description 42
- 238000000034 method Methods 0.000 title claims abstract description 26
- 239000012530 fluid Substances 0.000 claims abstract description 67
- 238000004519 manufacturing process Methods 0.000 claims abstract description 55
- 238000005065 mining Methods 0.000 claims abstract description 25
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 25
- 239000007787 solid Substances 0.000 claims description 19
- 239000003345 natural gas Substances 0.000 claims description 15
- 239000002245 particle Substances 0.000 claims description 10
- 238000009434 installation Methods 0.000 claims description 4
- 238000005553 drilling Methods 0.000 claims description 3
- 238000011084 recovery Methods 0.000 claims description 2
- 239000013505 freshwater Substances 0.000 abstract description 12
- 239000013535 sea water Substances 0.000 abstract description 12
- 230000000694 effects Effects 0.000 abstract description 11
- 238000004891 communication Methods 0.000 abstract description 2
- 239000007788 liquid Substances 0.000 description 10
- -1 natural gas hydrates Chemical class 0.000 description 5
- 238000005516 engineering process Methods 0.000 description 4
- 238000011161 development Methods 0.000 description 3
- 238000010276 construction Methods 0.000 description 2
- 238000001816 cooling Methods 0.000 description 2
- 238000000354 decomposition reaction Methods 0.000 description 2
- 238000007599 discharging Methods 0.000 description 2
- 238000004064 recycling Methods 0.000 description 2
- 230000001502 supplementing effect Effects 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 230000006837 decompression Effects 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000005265 energy consumption Methods 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000001737 promoting effect Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Images
Classifications
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- 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
-
- 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
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
-
- 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
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/40—Separation associated with re-injection of separated materials
-
- 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
- E21B7/00—Special methods or apparatus for drilling
- E21B7/18—Drilling by liquid or gas jets, with or without entrained pellets
- E21B7/185—Drilling by liquid or gas jets, with or without entrained pellets underwater
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Filling Or Discharging Of Gas Storage Vessels (AREA)
Abstract
The invention provides a natural gas hydrate heat injection exploitation system and a natural gas hydrate heat injection exploitation method, wherein a heat injection pipe column in the device is positioned in a production casing, outlet ends of the heat injection pipe column and the production casing extend into a hydrate reservoir, inlet ends of the heat injection pipe column and the production casing are connected with a wellhead device, and a packer is arranged between the heat injection pipe column and the production casing and close to the wellhead device. And a rotary jet eddy current device is arranged at one end of the heat injection pipe column, which is positioned at the hydrate reservoir. The inlet end of the hydrate fluid conduit is connected to a wellhead assembly and is in communication with the annulus between the heat injection string and the production casing. The mining system and the mining method provided by the invention can realize the high-efficiency mining effect of the hydrate, have simple structure, can meet the process requirements of mining trial production of the natural gas hydrate in a vertical well, an inclined well and a horizontal well, adopt hot fluid (fresh water or seawater) to cyclically mine the hydrate, improve the efficiency and save the production cost, thereby achieving the purposes of economy, high efficiency and strong operability.
Description
Technical Field
The invention relates to the technical field of natural gas hydrate development and exploitation, in particular to a natural gas hydrate heat injection exploitation system and a natural gas hydrate heat injection exploitation method.
Background
On a global scale, the development of the natural gas hydrate at the present stage is in a research test trial production stage, and the natural gas hydrate trial production work is performed in 5 countries including China, america and the like, so that some successful trial production experiences are obtained, and the trial production experiences show that the depressurization exploitation and the heat injection exploitation are good natural gas hydrate development modes. On the trial production method and the trial production system device, different methods and devices are adopted by various countries aiming at different mining conditions, and a mining trial production system which is reliable and economical in recognized technology is not formed.
Although the exploitation modes of the hydrate are different, the principle is that the temperature and pressure conditions of the stable existence of the natural gas hydrate are artificially broken, and the hydrate in the deposit is decomposed. Heat injection exploitation refers to pumping steam, hot water, hot brine or other hot fluids into a natural gas hydrate reservoir from the ground to promote temperature rise to achieve the purpose of hydrate decomposition; depressurization recovery refers to reducing the pressure of a hydrate reservoir, so that the formation pressure is lower than the pressure required by hydrate stability, and the purpose of promoting the decomposition of the natural gas hydrate is achieved. At present, various mining technologies have limitations of the technology, such as large heat loss and high energy consumption of a heating method, and are difficult to adapt to the process requirements of trial production of natural gas hydrates in a vertical well and an inclined well; the decompression mining speed is slow, and the efficiency is low. At present, no more perfect natural gas hydrate exploitation technology exists.
Disclosure of Invention
The invention aims to overcome the defects of the prior art and provides a natural gas hydrate heat injection exploitation system and a natural gas hydrate heat injection exploitation method, which can be applied to the field of natural gas hydrate heat injection exploitation trial exploitation engineering and meet the process requirements of exploiting and trial exploiting natural gas hydrates in vertical wells, inclined wells and horizontal wells.
In order to solve the technical problems, the technical scheme provided by the invention is as follows:
a natural gas hydrate heat injection production system comprises a heat injection pipe column and a hydrate fluid pipeline. The heat injection pipe column is positioned in the production casing, the outlet ends of the heat injection pipe column and the production casing extend into the hydrate reservoir, the inlet ends of the heat injection pipe column and the production casing are connected with a wellhead device, and a packer is arranged at a position, close to the wellhead device, between the heat injection pipe column and the production casing. And a rotary jet eddy current device is arranged at one end of the heat injection pipe column, which is positioned at the hydrate reservoir. The inlet end of the hydrate fluid conduit is connected to a wellhead assembly and is in communication with the annulus between the heat injection string and the production casing.
According to the natural gas hydrate heat injection exploitation system, hot fluid (fresh water or seawater) is injected into a hydrate reservoir through the heat injection pipe column, the underground rotary injection vortex tool performs rotary injection on the reservoir, the hydrate breakage rate is improved, the gas-liquid-solid three-phase vortex effect of the well bottom is enhanced, and after the hydrate fluid flows upwards along the annular space between the heat injection pipe column and the production casing out of the well mouth, natural gas, solid particles and the hot fluid are separated, so that the efficient exploitation effect of the hydrate is achieved. The exploitation system is simple in structure and can meet the process requirements of exploiting and trial-producing natural gas hydrates in vertical wells, inclined wells and horizontal wells.
With respect to the above technical solution, further improvements as described below can be made.
According to the natural gas hydrate heat injection production system, in a preferred embodiment, the outlet end of the hydrate fluid pipeline is provided with a separator, and the hot fluid separated by the separator is connected with the inlet end of the heat injection pipe column through a circulating pipeline.
Through the structure, the exploitation can be realized in a closed loop circulating system, the hydrate is cyclically exploited by adopting hot fluid (fresh water or seawater), the efficiency is improved, and the production cost is saved, so that the purposes of economy, high efficiency and strong operability are achieved.
Further, in a preferred embodiment, a pressure booster is provided between the outlet of the hot fluid on the separator and the inlet of the heat injection pipe column.
Through setting up the booster, can make the hot-fluid that separates out through the separator satisfy the pressure demand of heat injection exploitation when pouring into heat injection tubular column recycle, improve the exploitation efficiency.
Further, in a preferred embodiment, a heat exchanger and a control valve are sequentially arranged between the outlet of the hot fluid on the separator and the booster, and a heater is arranged between the booster and the inlet of the heat injection pipe column.
The hot fluid separated from the hydrate fluid by the separator enters the heat exchanger along the circulating pipeline for heat exchange and cooling, and then enters the water-hydrate reservoir through the heat injection pipe column after being reheated by the control valve, the supercharger and the heater, so that the purpose of reasonable recycling is achieved. The control valve can be used for supplementing liquid or discharging redundant liquid, so that the normal operation of the whole mining system is ensured, and the mining efficiency is improved in all directions. After the temperature of the liquid is reduced by the heat exchanger, the safety accident caused by overhigh temperature of the discharged redundant liquid can be avoided.
Specifically, in a preferred embodiment, the control valve is a four-way gate.
Through the four-way gate, normal temperature fluid (normal temperature fresh water or seawater) can be well supplemented into the circulating pipeline, or redundant liquid can be discharged.
In particular, in a preferred embodiment, the separator is a gas-liquid-solid three-phase separator.
The hydrate fluid is separated into natural gas, solid particles and hot fluid through a gas-liquid-solid three-phase separator, and the natural gas, the solid particles and the hot fluid are recycled through different channels, so that the exploitation efficiency can be effectively improved.
Further, in a preferred embodiment, centralizers are symmetrically arranged at two ends of the rotary jet vortex device.
Through the centralizers symmetrically arranged at the two ends of the rotary jet vortex device, the installation of the rotary jet vortex device in the heat injection pipe column can be ensured to be stable and reliable, and the working process of the rotary jet vortex device is prevented from being influenced.
Further, in a preferred embodiment, the outlet end of the hydrate fluid pipeline is provided with a guide plug.
The guide plug can effectively plug the heat injection pipe column in the non-exploitation stage, and the pipeline is prevented from leaking.
The natural gas hydrate heat injection exploitation method of the second aspect of the invention is implemented by adopting the exploitation system, and comprises the following steps: and S01, completing drilling and completion, and putting a production casing for completion. And S02, completing the installation of the mining system, and rotating the injection vortex tool to correspond to the preset position of the hydrate reservoir. S03, injecting hot fluid into a hydrate reservoir through the inlet end of the heat injection pipe column, rotationally injecting the hydrate reservoir by using a rotary injection vortex tool, enabling the hydrate fluid to flow upwards along an annular space between the heat injection pipe column and the production casing pipe to flow out of a well mouth, and then separating out natural gas, solid particles and the hot fluid.
Further, in a preferred embodiment, the gas hydrate heat injection exploitation method of the present invention further includes step S04, wherein the hot fluid separated in step S03 enters the inlet end of the hot fluid pipe column through the circulation pipeline.
Obviously, according to the natural gas hydrate heat injection exploitation method, due to the adoption of the exploitation system, the underground rotary injection vortex tool carries out rotary injection on the reservoir, the hydrate breakage rate is improved, the gas-liquid-solid three-phase vortex effect at the bottom of the well is enhanced, the efficient exploitation pilot-production effect of the hydrate is realized, the exploitation can be carried out in a closed-loop circulating system, the hydrate is cyclically exploited by adopting hot fluid (fresh water or seawater), the efficiency is improved, and the production cost is saved, so that the purposes of economy, high efficiency and strong operability are achieved.
Compared with the prior art, the invention has the advantages that: the hydrate mining device can achieve the efficient mining effect of the hydrate, is simple in structure, can meet the process requirements of mining and trial mining natural gas hydrates of vertical wells, inclined wells and horizontal wells, adopts hot fluid (fresh water or seawater) to cyclically mine the hydrate, improves the efficiency, and saves the production cost, so that the purposes of economy, high efficiency and strong operability are achieved.
Drawings
The invention will be described in more detail hereinafter on the basis of embodiments and with reference to the accompanying drawings. Wherein:
fig. 1 schematically shows the overall construction of a mining system of embodiment 1 of the invention;
figure 2 shows schematically the overall flow of the mining method of example 2 of the present invention.
Detailed Description
The invention will be described in further detail with reference to the following figures and specific examples, without thereby limiting the scope of protection of the invention.
Fig. 1 schematically shows the overall construction of a mining system 10 of embodiment 1 of the present invention. Figure 2 shows schematically the overall flow of the mining method of example 2 of the present invention.
Example 1
As shown in fig. 1, a gas hydrate heat injection production system 10 according to an embodiment of the present invention includes a heat injection pipe column 1 and a hydrate fluid pipeline 2. Wherein, heat injection pipe column 1 is located production casing 3, and the exit end of heat injection pipe column 1 and production casing 3 stretches into hydrate reservoir 101, and the entry end of heat injection pipe column 1 and production casing 3 is connected with wellhead assembly 4, and the position that is close to wellhead assembly between heat injection pipe column 1 and the production casing 3 is equipped with packer 5. And a rotary jet vortex device 6 is arranged at one end of the hydrate reservoir 101 in the heat injection pipe column 1. The inlet end of the hydrate fluid conduit 2 is connected to a wellhead 4 and communicates with the annulus between the heat injection string 1 and the production casing 3.
According to the natural gas hydrate heat injection exploitation system provided by the embodiment of the invention, hot fluid (fresh water or seawater) is injected into a hydrate reservoir through the heat injection pipe column, the underground rotary injection eddy current tool performs rotary injection on the reservoir, the hydrate breakage rate is improved, the gas-liquid-solid three-phase eddy current effect at the bottom of a well is enhanced, and after hydrate fluid flows upwards along the annular space between the heat injection pipe column and the production casing out of the well head, natural gas, solid particles and the hot fluid are separated, so that the high-efficiency exploitation effect of the hydrate is realized. The exploitation system is simple in structure and can meet the process requirements of exploiting and trial-producing natural gas hydrates in vertical wells, inclined wells and horizontal wells.
Further, in the present embodiment, as shown in fig. 1, the outlet end of the hydrate fluid pipeline 2 is provided with a separator 7, and the hot fluid separated by the separator 7 is connected with the inlet end of the heat injection pipe column 1 through a circulating pipeline. Through the structure, the exploitation can be realized in a closed loop circulating system, the hot fluid (fresh water or seawater) is adopted to circularly exploit the hydrate, the efficiency is improved, and the production cost is saved, so that the purposes of economy, high efficiency and strong operability are achieved. Specifically, in the present embodiment, the separator 7 is a gas-liquid-solid three-phase separator. The hydrate fluid is separated into natural gas, solid particles and hot fluid through a gas-liquid-solid three-phase separator, and the natural gas, the solid particles and the hot fluid are recycled through different channels, so that the exploitation efficiency can be effectively improved. Further, in the present embodiment, a pressure booster 8 is provided between the outlet of the hot fluid on the separator 7 and the inlet of the heat injection pipe column 1. Through setting up the booster, can make the hot-fluid that separates out through the separator satisfy the pressure demand of heat injection exploitation when pouring into heat injection tubular column recycle, improve the exploitation efficiency.
Further, in the present embodiment, as shown in fig. 1, a heat exchanger 9 and a control valve 102 are sequentially provided between the outlet of the hot fluid and the pressurizer 8 on the separator 7, and a heater 103 is provided between the pressurizer 8 and the inlet of the heat injection column 1. The hot fluid separated from the hydrate fluid by the separator enters the heat exchanger along the circulating pipeline for heat exchange and cooling, and then enters the water-hydrate reservoir through the heat injection pipe column after being reheated by the control valve, the supercharger and the heater, so that the purpose of reasonable recycling is achieved. The control valve can be used for supplementing liquid or discharging redundant liquid, so that the normal operation of the whole mining system is ensured, and the mining efficiency is improved in all directions. After the temperature of the heat exchanger is reduced, safety accidents caused by overhigh temperature of the discharged redundant liquid can be avoided. Specifically, in this embodiment, the control valve 102 is a four-way gate. Through the four-way gate, normal temperature fluid (normal temperature fresh water or seawater) can be well supplemented into the circulating pipeline, or redundant liquid can be discharged.
Further, as shown in fig. 1, in the present embodiment, centralizers 104 are symmetrically provided at both ends of the rotary jet vortex device 6. The centralizers are symmetrically arranged at the two ends of the rotary jet vortex device, so that the rotary jet vortex device can be stably and reliably installed in the heat injection pipe column, and the working process of the rotary jet vortex device is prevented from being influenced. Further, in this embodiment, the outlet end of the hydrate fluid pipeline 2 is provided with a guide plug 105. The guide plug can effectively plug the heat injection pipe column in the non-exploitation stage, and the pipeline is prevented from leaking.
As shown in fig. 1, specifically, in the present embodiment, a hot fluid flow direction 106, a hydrate fluid flow direction 107, a natural gas flow direction 108 and a solid particle flow direction 109 are respectively shown in the heat injection column 1.
Example 2
As shown in fig. 2, the natural gas hydrate heat injection production method according to the embodiment of the present invention is implemented by using the production system 10, and includes the following steps: and S01, completing drilling and completion, and putting a production casing into the well to complete the well. And S02, completing the installation of the mining system, and rotating the injection vortex tool to correspond to the preset position of the hydrate reservoir. S03, injecting hot fluid into a hydrate reservoir through the inlet end of the heat injection pipe column, rotationally injecting the hydrate reservoir by using a rotary injection vortex tool, enabling the hydrate fluid to flow upwards along an annular space between the heat injection pipe column and the production casing pipe to flow out of a well mouth, and then separating out natural gas, solid particles and the hot fluid.
Further, in this embodiment, the gas hydrate heat injection exploitation method further includes step S04, where the hot fluid separated in step S03 enters the inlet end of the hot fluid pipe column through a circulation pipeline.
Specifically, in this embodiment, normal temperature fresh water or seawater may be supplemented into the circulation pipeline or excess liquid may be discharged through the four-way gate, so as to ensure the stability and reliability of the whole mining process, thereby effectively improving the mining efficiency.
Obviously, according to the natural gas hydrate heat injection exploitation method provided by the embodiment of the invention, due to the adoption of the exploitation system 10 in the embodiment, the underground rotary injection vortex tool performs rotary injection on the reservoir, so that the hydrate breaking rate is improved, the gas-liquid-solid three-phase vortex effect at the bottom of the well is enhanced, the efficient exploitation pilot-exploitation effect of the hydrate is realized, the exploitation can be performed in a closed-loop circulating system, the hydrate is cyclically exploited by adopting hot fluid (fresh water or seawater), the efficiency is improved, and the production cost is saved, so that the purposes of economy, high efficiency and strong operability are achieved.
According to the embodiment, the natural gas hydrate heat injection exploitation system and the natural gas hydrate heat injection exploitation method can achieve the efficient exploitation effect of the hydrate, are simple in structure, can meet the technological requirements of exploiting and trial-exploiting the natural gas hydrate in a vertical well, an inclined well and a horizontal well, adopt hot fluid (fresh water or seawater) to cyclically exploit the hydrate, improve the efficiency and save the production cost, and therefore the purposes of economy, high efficiency and strong operability are achieved.
While the invention has been described with reference to a preferred embodiment, various modifications may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In particular, the technical features mentioned in the embodiments can be combined in any way as long as there is no structural conflict. It is intended that the invention not be limited to the particular embodiments disclosed, but that the invention will include all embodiments falling within the scope of the appended claims.
Claims (10)
1. The natural gas hydrate heat injection exploitation system is characterized by comprising a heat injection pipe column and a hydrate fluid pipeline; wherein, the first and the second end of the pipe are connected with each other,
the heat injection pipe column is positioned in the production casing, the outlet ends of the heat injection pipe column and the production casing extend into the hydrate reservoir, the inlet ends of the heat injection pipe column and the production casing are connected with a wellhead device, and a packer is arranged between the heat injection pipe column and the production casing and close to the wellhead device;
a rotary jet eddy current device is arranged at one end of the hydrate reservoir in the heat injection pipe column;
the inlet end of the hydrate fluid pipeline is connected with a wellhead device and is communicated with an annulus between the heat injection pipe column and the production casing.
2. The gas hydrate heat injection exploitation system of claim 1, wherein a separator is disposed at an outlet end of the hydrate fluid pipeline, and the hot fluid separated by the separator is connected to an inlet end of the heat injection string through a circulation pipeline.
3. The gas hydrate heat injection exploitation system of claim 2, wherein a pressure booster is provided between an outlet of hot fluid on the separator and an inlet of the heat injection string.
4. A natural gas hydrate heat injection and exploitation system as claimed in claim 3, wherein a heat exchanger and a control valve are sequentially disposed between the outlet of the hot fluid on the separator and the pressure booster, and a heater is disposed between the pressure booster and the inlet of the heat injection pipe column.
5. The gas hydrate heat injection recovery system of claim 4, wherein the control valve is a four-way gate.
6. A natural gas hydrate heat injection production system as claimed in any one of claims 2 to 5, wherein the separator is a gas-liquid-solid three-phase separator.
7. The natural gas hydrate heat injection and production system according to any one of claims 1 to 5, wherein centralizers are symmetrically arranged at two ends of the rotary jet vortex device.
8. A natural gas hydrate heat injection and production system as claimed in any one of claims 1 to 5, wherein the outlet end of the hydrate fluid pipeline is provided with a guide plug.
9. A gas hydrate heat injection production method implemented by the production system according to any one of claims 1 to 8, comprising the steps of:
s01, completing drilling and completion, and putting a production casing into the well to complete the well;
s02, completing the installation of the mining system, and rotating the injection vortex tool to correspond to the preset position of the hydrate reservoir;
s03, injecting hot fluid into a hydrate reservoir through the inlet end of the heat injection pipe column, rotationally injecting the hydrate reservoir by using a rotary injection vortex tool, enabling the hydrate fluid to flow upwards along an annular space between the heat injection pipe column and the production casing pipe to flow out of a well mouth, and then separating out natural gas, solid particles and the hot fluid.
10. The natural gas hydrate heat injection exploitation method according to claim 9, further comprising step S04, wherein the hot fluid separated in step S03 enters an inlet end of the hot fluid pipe column through a circulation pipe.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
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| CN202110550069.1A CN115370324A (en) | 2021-05-20 | 2021-05-20 | Natural gas hydrate heat injection exploitation system and method |
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| Application Number | Priority Date | Filing Date | Title |
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| CN202110550069.1A CN115370324A (en) | 2021-05-20 | 2021-05-20 | Natural gas hydrate heat injection exploitation system and method |
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| CN115370324A true CN115370324A (en) | 2022-11-22 |
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Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103615199A (en) * | 2013-11-28 | 2014-03-05 | 中国石油天然气股份有限公司 | Oil extraction processing device for achieving steam injection, oil extraction and temperature-pressure real-time monitoring in shaft of horizontal well with three tubes |
| CN105134152A (en) * | 2015-08-24 | 2015-12-09 | 中国石油大学(北京) | Method and system for extracting natural gas hydrate through thermal jet flow |
| CN105625998A (en) * | 2016-02-02 | 2016-06-01 | 西南石油大学 | Reverse production method and production equipment for seafloor natural gas hydrate stable layer |
| RU2624858C1 (en) * | 2016-07-27 | 2017-07-07 | Публичное акционерное общество "Татнефть" им. В.Д. Шашина | Recovery method of high-viscosity oil deposit by steam cyclic effect |
| RU2688821C1 (en) * | 2018-07-13 | 2019-05-22 | Ильдар Зафирович Денисламов | Multifunctional well for extraction of high-viscosity oil |
| CN111119798A (en) * | 2019-11-15 | 2020-05-08 | 东北石油大学 | Natural gas hydrate slurry mining device |
-
2021
- 2021-05-20 CN CN202110550069.1A patent/CN115370324A/en active Pending
Patent Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103615199A (en) * | 2013-11-28 | 2014-03-05 | 中国石油天然气股份有限公司 | Oil extraction processing device for achieving steam injection, oil extraction and temperature-pressure real-time monitoring in shaft of horizontal well with three tubes |
| CN105134152A (en) * | 2015-08-24 | 2015-12-09 | 中国石油大学(北京) | Method and system for extracting natural gas hydrate through thermal jet flow |
| CN105625998A (en) * | 2016-02-02 | 2016-06-01 | 西南石油大学 | Reverse production method and production equipment for seafloor natural gas hydrate stable layer |
| RU2624858C1 (en) * | 2016-07-27 | 2017-07-07 | Публичное акционерное общество "Татнефть" им. В.Д. Шашина | Recovery method of high-viscosity oil deposit by steam cyclic effect |
| RU2688821C1 (en) * | 2018-07-13 | 2019-05-22 | Ильдар Зафирович Денисламов | Multifunctional well for extraction of high-viscosity oil |
| CN111119798A (en) * | 2019-11-15 | 2020-05-08 | 东北石油大学 | Natural gas hydrate slurry mining device |
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