CN114427658B - Natural gas gathering and transportation method, device and gathering and transportation system for high-pressure condensate oil field - Google Patents
Natural gas gathering and transportation method, device and gathering and transportation system for high-pressure condensate oil field Download PDFInfo
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- CN114427658B CN114427658B CN202011054596.5A CN202011054596A CN114427658B CN 114427658 B CN114427658 B CN 114427658B CN 202011054596 A CN202011054596 A CN 202011054596A CN 114427658 B CN114427658 B CN 114427658B
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- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 95
- 239000003345 natural gas Substances 0.000 title claims abstract description 49
- 238000000034 method Methods 0.000 title claims abstract description 30
- 239000012530 fluid Substances 0.000 claims abstract description 65
- 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 claims abstract description 46
- 239000002245 particle Substances 0.000 claims abstract description 37
- 238000012546 transfer Methods 0.000 claims abstract description 5
- 239000003112 inhibitor Substances 0.000 claims description 15
- 238000006116 polymerization reaction Methods 0.000 claims description 14
- 230000007246 mechanism Effects 0.000 claims description 10
- 238000003756 stirring Methods 0.000 claims description 8
- 239000008239 natural water Substances 0.000 claims description 4
- 239000000463 material Substances 0.000 claims description 3
- 238000009827 uniform distribution Methods 0.000 claims description 3
- 238000004321 preservation Methods 0.000 claims description 2
- 238000005265 energy consumption Methods 0.000 abstract description 7
- 230000003044 adaptive effect Effects 0.000 abstract description 4
- 238000004088 simulation Methods 0.000 description 9
- 238000004519 manufacturing process Methods 0.000 description 8
- 239000007791 liquid phase Substances 0.000 description 7
- 230000002776 aggregation Effects 0.000 description 6
- 238000004220 aggregation Methods 0.000 description 6
- 230000008901 benefit Effects 0.000 description 6
- 239000007789 gas Substances 0.000 description 6
- 238000004458 analytical method Methods 0.000 description 5
- 230000008021 deposition Effects 0.000 description 5
- 238000005516 engineering process Methods 0.000 description 4
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 3
- 230000000903 blocking effect Effects 0.000 description 3
- 238000010438 heat treatment Methods 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- -1 natural gas hydrates Chemical class 0.000 description 3
- 239000012071 phase Substances 0.000 description 3
- 230000008569 process Effects 0.000 description 3
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 230000008859 change Effects 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 230000007613 environmental effect Effects 0.000 description 2
- 230000001052 transient effect Effects 0.000 description 2
- 150000001298 alcohols Chemical class 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000004134 energy conservation Methods 0.000 description 1
- 238000009413 insulation Methods 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17D—PIPE-LINE SYSTEMS; PIPE-LINES
- F17D1/00—Pipe-line systems
- F17D1/005—Pipe-line systems for a two-phase gas-liquid flow
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17D—PIPE-LINE SYSTEMS; PIPE-LINES
- F17D3/00—Arrangements for supervising or controlling working operations
- F17D3/01—Arrangements for supervising or controlling working operations for controlling, signalling, or supervising the conveyance of a product
Landscapes
- Engineering & Computer Science (AREA)
- Mechanical Engineering (AREA)
- General Engineering & Computer Science (AREA)
- Filling Or Discharging Of Gas Storage Vessels (AREA)
- Pipeline Systems (AREA)
Abstract
The invention provides a method and a device for gathering and transporting natural gas in a high-pressure condensate oil field and a gathering and transporting system, wherein the method comprises the following steps: acquiring target parameters of mixed fluid produced by an oil field at an oil field wellhead; step b: determining the pipe diameter of a conveying pipeline according to the target parameter and the conveying distance of the mixed fluid; step c: directing the mixed fluid into the transfer conduit, wherein natural gas hydrate particles are formed in the mixed fluid; step d: the natural gas hydrate particles are transported along the transport pipeline with the mixed fluid flowing. Based on the technical scheme of the invention, the pressure energy of the high-pressure wellhead of the high-pressure condensate oil field is fully utilized, the conveying energy consumption is reduced, an adaptive pressure environment is provided for the generation of the natural gas hydrate particles, meanwhile, the generation amount of the natural gas hydrate particles is controlled by controlling the pipe diameter of the conveying pipeline, and the risk of the mixed conveying pipeline that the hydrate is frozen and blocked is reduced.
Description
Technical Field
The invention relates to the technical field of natural gas conveying, in particular to a method and a device for gathering and conveying natural gas in a high-pressure condensate oil field and a gathering and conveying system.
Background
At present, in the period of great development of natural gas in China, the energy conservation and consumption reduction of a natural gas gathering and transportation system are beneficial to realizing the maximization of benefits of natural gas production, and the cost investment and economic benefits of the whole gas field production are directly related. The common natural gas gathering and transportation technology mainly comprises a wellhead heating throttling technology, a wellhead alcohol injection high-pressure gathering and transportation technology, a downhole throttling technology and the like. The wellhead heating throttling process can realize throttling and depressurization conveying of the gas well, and has higher energy consumption, lower utilization rate of the heating furnace during later pressurization and higher initial investment; the high-pressure gathering and transportation efficiency of methanol injection at the wellhead is high, but the recovery cost of alcohols is high, and the pollution is large; the underground throttling can effectively realize a low-pressure gas collection mode in which no alcohol is injected into the well head gas, but the throttler has short effective period, is easy to damage, has high maintenance and salvage cost and affects production.
The natural gas hydrate slurry mixing and conveying process can utilize pressure energy of a wellhead and reduce the injection amount of a hydrate inhibitor.
Disclosure of Invention
Aiming at the problems in the prior art, the application provides a method, a device and a system for gathering and transporting natural gas in a high-pressure condensate oil field, which fully utilize the pressure energy of a high-pressure wellhead of the high-pressure condensate oil field, reduce the transportation energy consumption and provide an adaptive pressure environment for the generation of natural gas hydrate particles. Meanwhile, according to the initial data of the mixed fluid, the generation amount of the natural gas hydrate particles is controlled by controlling the pipe diameter of the conveying pipeline, so that the risk of hydrate freeze blocking of the mixed conveying pipeline is reduced.
The invention relates to a natural gas gathering and transportation method for a high-pressure condensate oil field, which comprises the following steps:
step a: acquiring target parameters of mixed fluid produced by an oil field at an oil field wellhead;
Step b: determining the pipe diameter of a conveying pipeline according to the target parameter and the conveying distance of the mixed fluid;
Step c: directing the mixed fluid into the transfer conduit, wherein natural gas hydrate particles are formed in the mixed fluid;
Step d: the natural gas hydrate particles are transported along the transport pipeline with the mixed fluid flowing.
In one embodiment, the mixed fluid comprises natural gas, water, and condensate.
In one embodiment, the target parameters include flow, pressure, and temperature;
wherein the flow rate includes a total flow rate of the mixed fluid and a flow rate of each fluid constituting the mixed fluid.
In one embodiment, in step c, further comprising: and adding a polymerization inhibitor to the mixed fluid when the mixed fluid is guided into the conveying pipeline. With the present embodiment, the polymerization inhibitor is used to prevent aggregation of the natural gas hydrate particles in the mixed fluid, so that the natural gas hydrate particles are uniformly and stably dispersed and suspended in the continuous liquid phase without aggregation deposition.
In one embodiment, in step b, determining the wall thickness and the pipe material of the conveying pipe is further included.
In one embodiment, the conveying pipeline is further wrapped with an insulating layer. According to the embodiment, the purpose of the heat preservation layer is to ensure the proper temperature condition for generating the natural gas hydrate, and meanwhile, the problem that the natural gas hydrate is excessively generated due to the fact that the temperature is too low is avoided.
The invention relates to a natural gas gathering and transportation device, which is applied to the natural gas gathering and transportation method and comprises the following steps:
one end of the conveying pipeline is connected to a wellhead of the oil field;
The feeding mechanism is arranged at a wellhead connected with an oil field on the conveying pipeline and is used for adding polymerization inhibitor into mixed fluid in the conveying pipeline.
In one embodiment, the method further comprises: the stirring mechanism is arranged on the conveying pipeline and close to the feeding mechanism, and is used for stirring the mixed fluid so as to realize uniform distribution of the polymerization inhibitor in the mixed fluid.
The invention relates to a natural gas gathering and transportation system which comprises the natural gas gathering and transportation device.
In one embodiment, the system further comprises a temperature sensor, a pressure sensor and a flow sensor.
The above-described features may be combined in various suitable ways or replaced by equivalent features as long as the object of the present invention can be achieved.
Compared with the prior art, the method, the device and the system for gathering and transporting the natural gas in the high-pressure condensate oil field have the following beneficial effects:
According to the method, the device and the system for gathering and transporting the natural gas in the high-pressure condensate oil field, the pressure energy of the high-pressure wellhead of the high-pressure condensate oil field is fully utilized, the transportation energy consumption is reduced, an adaptive pressure environment is provided for the generation of natural gas hydrate particles, and the natural gas hydrate particles are transported by liquid phase fluid mixing, so that the addition amount of a polymerization inhibitor is small, and the production cost is reduced. Meanwhile, the pipe diameter of the conveying pipeline is controlled according to the initial data of the mixed fluid, so that the proper generation amount of the natural gas hydrate particles is controlled, the risk of hydrate freeze blocking of the mixed conveying pipeline is reduced, and better economic benefit and environmental benefit 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 shows a flow chart of the method of the present invention;
FIG. 2 shows a plot of the volume fraction of natural gas hydrate particles along a transport pipeline from a simulated analysis according to the method of the present invention;
FIG. 3 shows a graph of pressure versus temperature along a conveying pipeline obtained by simulation analysis according to the method of the present invention;
In the drawings, like parts are designated with like reference numerals. The figures are not to scale.
Detailed Description
The invention will be further described with reference to the accompanying drawings.
Example 1
This example mainly illustrates the technical principle of the method of the present invention.
The embodiment provides a natural gas gathering and transportation method for a high-pressure condensate oil field, which is characterized by comprising the following steps:
Step a: and obtaining target parameters of mixed fluid produced by the oil field at an oil field wellhead, wherein the mixed fluid comprises natural gas, water and condensate oil.
Specifically, the high-pressure condensate oil field belongs to a special oil field, and the output of the high-pressure condensate oil field is mixed fluid with various components, including natural gas, water and condensate oil. The target parameters include flow, pressure, and temperature; wherein the flow rate includes a total flow rate of the mixed fluid and a flow rate of each fluid constituting the mixed fluid.
Step b: determining the pipe diameter of a conveying pipeline and the wall thickness and the pipeline material of the conveying pipeline according to the target parameters and the conveying distance of the mixed fluid;
Specifically, since the specific value of the target parameter is determined by the inherent property of the oil field, the specific value cannot be changed artificially, and the control of the pipe diameter of the conveying pipeline is further converted into the control of the generation condition of the natural gas hydrate particles, specifically, the control of the pressure, the flow and the temperature in the conveying pipeline. The greater the pressure and the lower the temperature under certain conditions, the more easily natural gas hydrate particles are formed.
Step c: adding a polymerization inhibitor into the mixed fluid and guiding the mixed fluid into a conveying pipeline, wherein natural gas hydrate particles are formed in the mixed fluid in the conveying pipeline;
in particular, the polymerization inhibitor is used to prevent aggregation of the natural gas hydrate particles in the mixed fluid, so that the natural gas hydrate particles are uniformly and stably dispersed and suspended in the continuous liquid phase without aggregation and deposition.
Step d: the natural gas hydrate particles are transported along the transport pipeline along with the mixed fluid.
In particular, conventional natural gas delivery is in the form of a gas, which is required to prevent the formation of natural gas hydrates, which are present in solid form and thus easily cause clogging of the pipeline.
The main technical means of the invention is to carry out natural gas transportation by forming the natural gas hydrate particles, and a certain volume of natural gas hydrate can be converted into more than 100 times of natural gas, so that the natural gas transportation by adopting the natural gas hydrate particles has extremely high efficiency.
The method is applied to the high-pressure condensate oil field, and the high-pressure condensate oil field generates fluid containing a liquid phase of natural gas, so that the generated natural gas hydrate particles flow along with the fluid of the liquid phase, and the risks of aggregation deposition and blockage caused by deposition are small. Meanwhile, the method of the invention directly guides the fluid produced by the wellhead to enter the pipeline for transportation based on the fluid property at the wellhead of the high-pressure condensate oil field, so that the generation condition of the natural gas hydrate can be controlled by controlling the size of the transportation pipeline according to the fluid property at the wellhead and related parameters, thereby controlling the generation amount of the natural gas hydrate, and finally ensuring that the generation amount of the natural gas hydrate is not excessive to cause blockage, and further reducing the risk of blockage.
Preferably, the conveying pipeline is also wrapped with an insulating layer.
In particular, the purpose of the insulation layer is to ensure the temperature conditions suitable for the formation of natural gas hydrates, while avoiding the problem of excessive formation of natural gas hydrates caused by too low a temperature.
Example 2
This example mainly illustrates the process of an actual simulation analysis based on multiphase flow transient simulation analysis software OLGA, performed according to the method of the present invention.
Step a: acquiring and inputting the flow of the mixed fluid, the pressure of a conveying starting point and a conveying end point and the temperature of the starting point;
Specifically, the input oil phase flow rate is 53m3/d, the water phase flow rate is 18m3/d, the gas phase flow rate is 1.9X104 m3/d, the starting point pressure is 6.4Mpa, the end point pressure is 4Mpa or 10Mpa, the end point pressure is 8Mpa, and the starting point temperature is 29 ℃.
Step b: c, determining that the pipe diameter of the conveying pipeline is 80mm and the pipe length is 10km according to the related parameters input in the step a;
step c: the multiphase flow transient simulation analysis software performs simulation analysis based on the data.
Specifically, the simulation analysis results are shown in fig. 1 and 2 of the accompanying drawings. Wherein, the abscissa in fig. 1 is the conveying distance, the ordinate is the volume fraction of the natural gas hydrate particles, and the abscissa in fig. 2 is the conveying distance, the ordinate is the pressure (dark number) and the temperature (light number) inside the conveying pipeline.
According to the simulation result shown in fig. 1, the production of the natural gas hydrate particles starts to have at a distance of 2.5km from the start point in the transport pipe, and the production amount of the natural gas hydrate particles increases continuously with the increase of the transport distance, and the production amount of the natural gas hydrate particles is expressed as a volume fraction thereof in the mixed fluid. At the end of the transfer, the volume fraction of the gas hydrate particles reached a maximum of 7% by volume.
According to the simulation result shown in fig. 2 and fig. 1, under the preset condition, the pressure change curve (dark line) along the conveying pipeline is smooth and no peak value phenomenon of pressure steep increase occurs, which indicates that the condition that the conveying pipeline is not blocked by natural gas hydrate occurs, and further proves the correctness of the technical means of selecting the pipe diameter of the conveying pipeline according to the fluid parameters at the wellhead. Meanwhile, the temperature drop caused by heat transfer along the pipeline is counteracted by heat released during generation of the natural gas hydrate in the conveying pipeline, so that the temperature change curve (light line) in fig. 2 shows that the temperature along the conveying pipeline is basically unchanged after being 2.5km away from the starting point of the pipeline, stable temperature also provides stable generation conditions for the natural gas hydrate particles, and the generation amount of the natural gas hydrate particles is controlled on the premise of keeping normal generation of the natural gas hydrate particles.
According to the simulation result, the natural gas gathering and transportation method fully utilizes the pressure energy of the high-pressure wellhead of the high-pressure condensate oil field, reduces the transportation energy consumption, provides an adaptive pressure environment for the generation of natural gas hydrate particles, and reduces the production cost because the natural gas hydrate particles are transported by liquid phase fluid mixing, and the addition amount of the polymerization inhibitor is small. Meanwhile, the pipe diameter of the conveying pipeline is controlled according to the initial data of the mixed fluid, so that the proper generation amount of the natural gas hydrate particles is controlled, the risk of hydrate freeze blocking of the mixed conveying pipeline is reduced, and better economic benefit and environmental benefit are achieved.
Example 3
The embodiment provides a natural gas gathering and transportation device, which applies the natural gas gathering and transportation method, and comprises the following steps:
one end of the conveying pipeline is connected to a wellhead of the oil field;
and the feeding mechanism is arranged at a wellhead connected with the oil field on the conveying pipeline and is used for adding polymerization inhibitor into the mixed fluid in the conveying pipeline.
Specifically, the conveying pipeline is directly connected to the wellhead, and other structures are not arranged in the middle of the conveying pipeline, so that the complexity of the conveying structure is reduced, meanwhile, the pressure energy at the wellhead is fully utilized, and the conveying energy consumption is reduced. Meanwhile, the natural gas gathering and transportation device of the embodiment applies the natural gas gathering and transportation method, and further has all technical effects of the natural gas gathering and transportation device.
In one embodiment, further comprising:
And the stirring mechanism is arranged on the conveying pipeline and close to the feeding mechanism, and is used for stirring the mixed fluid so as to realize uniform distribution of the polymerization inhibitor in the mixed fluid.
Specifically, the stirring mechanism is used for stirring the mixed fluid, so that the added polymerization inhibitor is uniformly distributed in the mixed fluid, and further, the generated natural gas hydrate particles are uniformly and stably dispersed and suspended in the continuous liquid phase without aggregation and deposition.
Example 4
The embodiment provides a natural gas gathering and transportation system, and the natural gas gathering and transportation device.
Preferably, a temperature sensor, a pressure sensor and a flow sensor are also included.
Specifically, the temperature sensor, the pressure sensor and the flow sensor are arranged along the conveying pipeline and used for detecting the pressure, the temperature and the flow in the conveying pipeline and reflecting the conveying condition of the fluid in the conveying pipeline in real time. Meanwhile, the natural gas gathering and transportation system of the embodiment comprises the natural gas gathering and transportation device, and further has all technical effects of the natural gas gathering and transportation device.
In the description of the present invention, it should be understood that the terms "upper," "lower," "bottom," "top," "front," "rear," "inner," "outer," "left," "right," and the like indicate or are based on the orientation or positional relationship shown in the drawings, merely to facilitate description of the present invention and to simplify the description, and do not indicate or imply that the devices or elements referred to must have a particular orientation, be configured and operated in a particular orientation, and thus should not be construed as limiting the present invention.
Although the invention herein has been described with reference to particular embodiments, it is to be understood that these embodiments are merely illustrative of the principles and applications of the present invention. It is therefore to be understood that numerous modifications may be made to the illustrative embodiments and that other arrangements may be devised without departing from the spirit and scope of the present invention as defined by the appended claims. It should be understood that the different dependent claims and the features described herein may be combined in ways other than as described in the original claims. It is also to be understood that features described in connection with separate embodiments may be used in other described embodiments.
Claims (8)
1. The method for gathering and transporting the natural gas in the high-pressure condensate oil field is characterized by comprising the following steps of:
Step a: acquiring target parameters of mixed fluid produced by an oil field at an oil field wellhead; the target parameters include flow, pressure and temperature; wherein the flow rate includes a total flow rate of the mixed fluid and a flow rate of each fluid constituting the mixed fluid;
Step b: determining the pipe diameter of a conveying pipeline according to the target parameter and the conveying distance of the mixed fluid;
Step c: directing the mixed fluid into the transfer conduit, wherein natural gas hydrate particles are formed in the mixed fluid; adding a polymerization inhibitor to the mixed fluid while the mixed fluid is directed into the delivery conduit;
Step d: the natural gas hydrate particles are transported along the transport pipeline with the mixed fluid flowing.
2. The method of claim 1, wherein the mixed fluid comprises natural gas, water, and condensate.
3. The method of claim 1, further comprising determining the wall thickness and the material of the pipeline in step b.
4. The method for gathering and transporting natural gas in high pressure condensate fields as recited in claim 1, wherein said transportation pipeline is further wrapped with a heat preservation layer.
5. A natural gas gathering and transportation apparatus employing the natural gas gathering and transportation method as defined in any one of claims 1 to 4, comprising:
one end of the conveying pipeline is connected to a wellhead of the oil field;
The feeding mechanism is arranged at a wellhead connected with an oil field on the conveying pipeline and is used for adding polymerization inhibitor into mixed fluid in the conveying pipeline.
6. The natural gas gathering and transportation device as recited in claim 5, further comprising:
The stirring mechanism is arranged on the conveying pipeline and close to the feeding mechanism, and is used for stirring the mixed fluid so as to realize uniform distribution of the polymerization inhibitor in the mixed fluid.
7. A natural gas gathering and transportation system, characterized in that it comprises the natural gas gathering and transportation device according to claim 5 or 6.
8. The natural gas gathering system as recited in claim 7, further comprising a temperature sensor, a pressure sensor, and a flow sensor.
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| CN202011054596.5A CN114427658B (en) | 2020-09-29 | 2020-09-29 | Natural gas gathering and transportation method, device and gathering and transportation system for high-pressure condensate oil field |
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| CN202011054596.5A CN114427658B (en) | 2020-09-29 | 2020-09-29 | Natural gas gathering and transportation method, device and gathering and transportation system for high-pressure condensate oil field |
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| CN105221847A (en) * | 2015-09-21 | 2016-01-06 | 常州大学 | A kind of gas hydrates Cemented filling and decomposing unit |
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| Publication number | Priority date | Publication date | Assignee | Title |
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| US8161998B2 (en) * | 2007-06-04 | 2012-04-24 | Matos Jeffrey A | Frozen/chilled fluid for pipelines and for storage facilities |
| US7192486B2 (en) * | 2002-08-15 | 2007-03-20 | Applied Materials, Inc. | Clog-resistant gas delivery system |
| US20050214079A1 (en) * | 2004-02-17 | 2005-09-29 | Lovie Peter M | Use of hydrate slurry for transport of associated gas |
| CN105443988B (en) * | 2015-11-13 | 2017-12-01 | 海洋石油工程股份有限公司 | Gas hydrates block method for removing blockage in a kind of multiphase transportation pipeline |
| CN105465605B (en) * | 2015-11-16 | 2018-06-08 | 江苏中圣高科技产业有限公司 | A kind of efficient energy-saving steam extra long distance carrying method and system |
| CN105545279B (en) * | 2016-01-29 | 2018-08-21 | 西南石油大学 | A kind of defeated device of the pipe of gas hydrates |
| CN109296939A (en) * | 2018-10-26 | 2019-02-01 | 碎得机械(北京)有限公司 | A kind of hazardous waste pipeline pressure monitoring method and its monitoring early-warning system |
| CN111119795A (en) * | 2019-12-09 | 2020-05-08 | 森诺科技有限公司 | Novel gas production process |
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Patent Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102927442A (en) * | 2012-11-15 | 2013-02-13 | 常州大学 | Gas hydrate pipeline conveying method and gas hydrate pipeline conveying device |
| CN105221847A (en) * | 2015-09-21 | 2016-01-06 | 常州大学 | A kind of gas hydrates Cemented filling and decomposing unit |
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