CA2567413A1 - Method and apparatus for extracting gas hydrate - Google Patents
Method and apparatus for extracting gas hydrate Download PDFInfo
- Publication number
- CA2567413A1 CA2567413A1 CA002567413A CA2567413A CA2567413A1 CA 2567413 A1 CA2567413 A1 CA 2567413A1 CA 002567413 A CA002567413 A CA 002567413A CA 2567413 A CA2567413 A CA 2567413A CA 2567413 A1 CA2567413 A1 CA 2567413A1
- Authority
- CA
- Canada
- Prior art keywords
- natural gas
- deposit
- gas hydrates
- water
- reactor module
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 238000000034 method Methods 0.000 title claims abstract description 19
- 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 description 11
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims abstract description 62
- 239000003345 natural gas Substances 0.000 claims abstract description 43
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 40
- 238000010438 heat treatment Methods 0.000 claims abstract description 27
- -1 natural gas hydrates Chemical class 0.000 claims abstract description 24
- 239000002904 solvent Substances 0.000 claims abstract description 14
- 239000007789 gas Substances 0.000 claims description 15
- 238000004519 manufacturing process Methods 0.000 claims description 14
- 150000004677 hydrates Chemical class 0.000 claims description 13
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical group OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 claims description 9
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 claims description 6
- 230000006698 induction Effects 0.000 claims description 6
- 230000004907 flux Effects 0.000 claims description 3
- 239000008400 supply water Substances 0.000 claims description 2
- 238000002347 injection Methods 0.000 abstract description 18
- 239000007924 injection Substances 0.000 abstract description 18
- 230000015572 biosynthetic process Effects 0.000 description 12
- 239000012530 fluid Substances 0.000 description 7
- 238000000605 extraction Methods 0.000 description 4
- 239000000203 mixture Substances 0.000 description 3
- 238000005553 drilling Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 1
- 239000013078 crystal Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000012466 permeate Substances 0.000 description 1
- 239000002798 polar solvent Substances 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 238000004064 recycling Methods 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
Classifications
-
- 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
- E21B43/2401—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection by means of electricity
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/0099—Equipment or details not covered by groups E21B15/00 - E21B40/00 specially adapted for drilling for or production of natural hydrate or clathrate gas reservoirs; Drilling through or monitoring of formations containing gas hydrates or clathrates
Landscapes
- 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)
- Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
Abstract
An apparatus and method for disassociating natural gas from a deposit of natural gas hydrates and producing natural gas. A reactor module is located downhole in a heating and injection well. Water is provided to the reactor module where it is heated and a solvent is injected into the water prior to heating. The heated water and solvent passes to the deposit of natural gas hydrates where the natural gas is disassociated under the influence of the heat from the reactor module.
Description
TITLE
METHOD AND APPARATUS FOR EXTRACTING GAS HYDRATE DEPOSITS
BACKGROUND OF THE INVENTION
Natural gas hydrate deposits are known to exist in numerous regions in great quantities in the world and contain many times the known producible reserves of conventional natural gas. Natural gas hydrates are crystals of principally methane within a lattice of water molecules and are formed naturally under conditions of low temperature and high pressure. The deposits can generally can be reached using conventional well drilling and well completion technology. However, heating and disassociating such deposits to release the trapped natural gas is a problem.
METHOD AND APPARATUS FOR EXTRACTING GAS HYDRATE DEPOSITS
BACKGROUND OF THE INVENTION
Natural gas hydrate deposits are known to exist in numerous regions in great quantities in the world and contain many times the known producible reserves of conventional natural gas. Natural gas hydrates are crystals of principally methane within a lattice of water molecules and are formed naturally under conditions of low temperature and high pressure. The deposits can generally can be reached using conventional well drilling and well completion technology. However, heating and disassociating such deposits to release the trapped natural gas is a problem.
SUNIlMARY OF THE INVENTION
According to one aspect of the invention, there is provided a method of extracting natural gas from a deposit of natural gas hydrates, said method comprising supplying water to said deposit of said natural gas hydrates, heating said water supplied to said deposit of natural gas hydrates and flooding said deposit of said natural gas hydrates to disassociate said natural gas hydrates in order to recover said natural gas and the water from said disassociation of said natural gas hydrates, said natural gas and said water migrating from said deposit of natural gas hydrates to an area of lower pressure being production casing.
According to a further aspect of the invention, there is provided apparatus for heating a deposit of gas hydrates to disassociate said gas hydrates and obtain natural gas comprising a reactor module located within casing of a heating well, a water injector to supply water to said reactor module and a heater within said reactor module to heat said water supplied to said reactor module and to inject said heated water into said deposit of gas hydrates.
According to yet a further aspect of the invention, there is provided a method of heating a deposit of natural gas hydrates comprising positioning an induction tool in downhole well casing and generating an induction flux in said tool to excite and heat said well casing and said deposit of natural gas hydrates.
BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS
Specific embodiments of the invention will now be described, by way of example only, with the use of drawings in which:
Figure 1 is a diagrammatic layout illustrating the overall technique for extraction of the natural gases from the natural gas hydrate formation; and ' Figure 2 is a diagrammatic plan view of a plurality of injector and heating wells drilled about the boundaries of a natural gas hydrate formation.
According to one aspect of the invention, there is provided a method of extracting natural gas from a deposit of natural gas hydrates, said method comprising supplying water to said deposit of said natural gas hydrates, heating said water supplied to said deposit of natural gas hydrates and flooding said deposit of said natural gas hydrates to disassociate said natural gas hydrates in order to recover said natural gas and the water from said disassociation of said natural gas hydrates, said natural gas and said water migrating from said deposit of natural gas hydrates to an area of lower pressure being production casing.
According to a further aspect of the invention, there is provided apparatus for heating a deposit of gas hydrates to disassociate said gas hydrates and obtain natural gas comprising a reactor module located within casing of a heating well, a water injector to supply water to said reactor module and a heater within said reactor module to heat said water supplied to said reactor module and to inject said heated water into said deposit of gas hydrates.
According to yet a further aspect of the invention, there is provided a method of heating a deposit of natural gas hydrates comprising positioning an induction tool in downhole well casing and generating an induction flux in said tool to excite and heat said well casing and said deposit of natural gas hydrates.
BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS
Specific embodiments of the invention will now be described, by way of example only, with the use of drawings in which:
Figure 1 is a diagrammatic layout illustrating the overall technique for extraction of the natural gases from the natural gas hydrate formation; and ' Figure 2 is a diagrammatic plan view of a plurality of injector and heating wells drilled about the boundaries of a natural gas hydrate formation.
DESCRIPTION OF SPECIFIC EMBODIMENT
Referring now to the drawings, a natural gas hydrate formation is generally illustrated at 100. The formation may be located at relatively shallow or relatively deep depth and conventional well drilling and well completion is sufficient to reach the formation 100.
A production well 101 is drilled and put into operation using conventional technology. A horizontal portion 102 extends into the gas hydrate formation 100 and a perforated production liner 103 is installed at the retrieval area of,the natural gas hydrate formation 100.
A pump 122 is located downhole in the production well 101 for the purpose of pumping the water produced from the disassociation of gas hydrates to the surface 111.
Natural gas from the dissociated hydrate flows to the surface within the production casing where a compressor (not illustrated) is located to compress and transport the recovered gas.
A second drill hole, namely an injection and heating well is generally illustrated at 104. It extends from the surface 111 substantially vertically in a vertical portion 112 and terminates at the end of a horizontal portion 113. A water injection unit 120 and a water tank 121 are located on the surface 111 and act to provide water and a polar solvent such as methanol or ethylene glycol solvent for injection into the injection and heating well 104. The use of solvent prevents the re-association of the water and the natural gas into hydrates causing blockage of production.
A reactive module according to the invention is generally illustrated at 114. It is located within the horizontal portion 113 of the heating and injection well 104. The reactive module 114 takes the form generally illustrated in United States Patent 6,384,389, the contents of which are incorporated by reference. The reactive module 114 has a hollow bore and in a first embodiment, it is inductively powered; that is, it projects electromagnetic flux outwardly to optimally heat the steel well casing 123 of the injection and heating well 104. A hydraulic pump 124 is provided within the reactor module 114 which hydraulic pump 124 utilizes a motor driven piston contained within a cylinder. The hydraulic pump 124 provides pressure.to a bladder 130 which seals the reactor module 114 within the well casing 123 as will be described. Telemetry and control electronics are provided within the reactor module 114 to monitor various sensors and transducers embedded within the reactor module 114 which sensors and transducers are used to measure process variables such as downhole temperatures and pressures, as well as to control actuation of the reactor module 114, the hydraulic pump 124, the bladder or seal 130, the fluid removal pump 122 and the methanol injection process taking place in the water injection unit 120. A DC to AC inverter is provided to supply power to the reactor module 114.
The downhole tooling used to install and operate the reactor module 114 includes centralizers (not illustrated) to maintain the reactor module 114 centrally located within the injection and heating well 113 as is known and the reactor module 114 is supported by tubing (not illustrated) supplied from the topside tube spool as is also known. The tubing incorporates a high pressure tube for the supply of solvent, a fluid extraction tube for extraction of fluids, a power cable and a data - 7 - ~
telemetry cable all as is known. The topside tubing spool will further include the necessary electrical and fluid slip rings to interface the downhole tool with the topside subsystems used to process the downhole data.
A power control unit(PCU) (not illustrated) controls three phase power to high voltage DC power to be supplied to operate the reactor module 114. The PCU
provides an operator interface and the control logic.
The gas extraction system used by the production well 101 enhances the separation of the natural gas from the water flowing.from the production well 101. The gas extracted from the gas hydrate formation to the surface 111 is then compressed for storage and/or transport.
A fluid separator subsystem (not illustrated) separates water and solvent fluid pumped out of the production well 101. The water is collected for recycling to the solvent mixing systems, with excess water going to disposal. Recovered solvent plus the addition of any required make-up is mixed with water to an optimal concentration and re-injected into the injection and heating well 112.
OPERATION
Using the downhole tooling previous,ly described, the reactor module 114 is deployed to its initial operating position within the horizontal portion 113 of the injection and heating well 104. The operation of the hydraulic pump 124 is initiated and the bladder or seal 130 is inflated in order to provide a pressure seal between the reactor module 114 and the casing 123. The reactor module 114 is powered on to heat the well casing 123 and the injected solvent/water mixture causing the hydrate within the gas hydrate formation to disassociate into a two phase gas and fluid mixture. Hot,water permeates the formation causing the hydrates and water to migrate to the lower pressure perforated production liner 103. Water within the casing is pumped to the surface 113 by pump 122. Solvent is injected into the water being supplied to the injection and heating well 104 from injection unit 120. The injected solvent/water mixture may be partially or completely vaporized by the heat generated by the reactor modules thus forming a high pressure vapor "cloud" which emanates from the injection liner 131. The vapor "cloud" expands the heating zone further into the gas hydrate formation 100 which contributes further to the disassociation of the gas hydrates resulting in increasing amounts of natural gas being passed to the low.pressure zone of the perforated production liner 103 and into the production well 101 where it passes to the surface 113.
The reactor module 114 is moved along the horizontal portion 102 of the heating and injection well 104. Prior to movement, the bladder or seal 130 is deflated to allow.for movement of the reactor module 114 and when the new operating position of the reactor module 114 is reached, the bladder or seal 130 is inflated to provide a new seal between the reactor module 114 and the casing 123. As the movement of the reactor module 114 takes place, the heated zone within the gas hydrates formation is increased and expanded to disassociate the gas hydrates and thereby to contribute to more complete natural gas flow to the production well 101.
While the reactor module 114 has been _ 10 _ illustrated and described in a horizontal portion of the injection and heating well 104, it is apparent that the benefits of the invention would also apply equally to the reactor module 114 being deployed in a vertical well or a slant well. Thus, the reactor module 114 may be deployed and operated in an injection and heating well of virtually any configuration.
Many further modifications in the invention will readily occur to those skilled in the art to which the invention relates and the specific embodiments described herein should be taken as illustrative of the invention only and not as limiting its scope as defined in accordance with the accompanying claims.
Referring now to the drawings, a natural gas hydrate formation is generally illustrated at 100. The formation may be located at relatively shallow or relatively deep depth and conventional well drilling and well completion is sufficient to reach the formation 100.
A production well 101 is drilled and put into operation using conventional technology. A horizontal portion 102 extends into the gas hydrate formation 100 and a perforated production liner 103 is installed at the retrieval area of,the natural gas hydrate formation 100.
A pump 122 is located downhole in the production well 101 for the purpose of pumping the water produced from the disassociation of gas hydrates to the surface 111.
Natural gas from the dissociated hydrate flows to the surface within the production casing where a compressor (not illustrated) is located to compress and transport the recovered gas.
A second drill hole, namely an injection and heating well is generally illustrated at 104. It extends from the surface 111 substantially vertically in a vertical portion 112 and terminates at the end of a horizontal portion 113. A water injection unit 120 and a water tank 121 are located on the surface 111 and act to provide water and a polar solvent such as methanol or ethylene glycol solvent for injection into the injection and heating well 104. The use of solvent prevents the re-association of the water and the natural gas into hydrates causing blockage of production.
A reactive module according to the invention is generally illustrated at 114. It is located within the horizontal portion 113 of the heating and injection well 104. The reactive module 114 takes the form generally illustrated in United States Patent 6,384,389, the contents of which are incorporated by reference. The reactive module 114 has a hollow bore and in a first embodiment, it is inductively powered; that is, it projects electromagnetic flux outwardly to optimally heat the steel well casing 123 of the injection and heating well 104. A hydraulic pump 124 is provided within the reactor module 114 which hydraulic pump 124 utilizes a motor driven piston contained within a cylinder. The hydraulic pump 124 provides pressure.to a bladder 130 which seals the reactor module 114 within the well casing 123 as will be described. Telemetry and control electronics are provided within the reactor module 114 to monitor various sensors and transducers embedded within the reactor module 114 which sensors and transducers are used to measure process variables such as downhole temperatures and pressures, as well as to control actuation of the reactor module 114, the hydraulic pump 124, the bladder or seal 130, the fluid removal pump 122 and the methanol injection process taking place in the water injection unit 120. A DC to AC inverter is provided to supply power to the reactor module 114.
The downhole tooling used to install and operate the reactor module 114 includes centralizers (not illustrated) to maintain the reactor module 114 centrally located within the injection and heating well 113 as is known and the reactor module 114 is supported by tubing (not illustrated) supplied from the topside tube spool as is also known. The tubing incorporates a high pressure tube for the supply of solvent, a fluid extraction tube for extraction of fluids, a power cable and a data - 7 - ~
telemetry cable all as is known. The topside tubing spool will further include the necessary electrical and fluid slip rings to interface the downhole tool with the topside subsystems used to process the downhole data.
A power control unit(PCU) (not illustrated) controls three phase power to high voltage DC power to be supplied to operate the reactor module 114. The PCU
provides an operator interface and the control logic.
The gas extraction system used by the production well 101 enhances the separation of the natural gas from the water flowing.from the production well 101. The gas extracted from the gas hydrate formation to the surface 111 is then compressed for storage and/or transport.
A fluid separator subsystem (not illustrated) separates water and solvent fluid pumped out of the production well 101. The water is collected for recycling to the solvent mixing systems, with excess water going to disposal. Recovered solvent plus the addition of any required make-up is mixed with water to an optimal concentration and re-injected into the injection and heating well 112.
OPERATION
Using the downhole tooling previous,ly described, the reactor module 114 is deployed to its initial operating position within the horizontal portion 113 of the injection and heating well 104. The operation of the hydraulic pump 124 is initiated and the bladder or seal 130 is inflated in order to provide a pressure seal between the reactor module 114 and the casing 123. The reactor module 114 is powered on to heat the well casing 123 and the injected solvent/water mixture causing the hydrate within the gas hydrate formation to disassociate into a two phase gas and fluid mixture. Hot,water permeates the formation causing the hydrates and water to migrate to the lower pressure perforated production liner 103. Water within the casing is pumped to the surface 113 by pump 122. Solvent is injected into the water being supplied to the injection and heating well 104 from injection unit 120. The injected solvent/water mixture may be partially or completely vaporized by the heat generated by the reactor modules thus forming a high pressure vapor "cloud" which emanates from the injection liner 131. The vapor "cloud" expands the heating zone further into the gas hydrate formation 100 which contributes further to the disassociation of the gas hydrates resulting in increasing amounts of natural gas being passed to the low.pressure zone of the perforated production liner 103 and into the production well 101 where it passes to the surface 113.
The reactor module 114 is moved along the horizontal portion 102 of the heating and injection well 104. Prior to movement, the bladder or seal 130 is deflated to allow.for movement of the reactor module 114 and when the new operating position of the reactor module 114 is reached, the bladder or seal 130 is inflated to provide a new seal between the reactor module 114 and the casing 123. As the movement of the reactor module 114 takes place, the heated zone within the gas hydrates formation is increased and expanded to disassociate the gas hydrates and thereby to contribute to more complete natural gas flow to the production well 101.
While the reactor module 114 has been _ 10 _ illustrated and described in a horizontal portion of the injection and heating well 104, it is apparent that the benefits of the invention would also apply equally to the reactor module 114 being deployed in a vertical well or a slant well. Thus, the reactor module 114 may be deployed and operated in an injection and heating well of virtually any configuration.
Many further modifications in the invention will readily occur to those skilled in the art to which the invention relates and the specific embodiments described herein should be taken as illustrative of the invention only and not as limiting its scope as defined in accordance with the accompanying claims.
Claims (12)
1. A method of extracting natural gas from a deposit of natural gas hydrates, said method comprising supplying water to said deposit of said natural gas hydrates, heating said water supplied to said deposit of natural gas hydrates and flooding said deposit of said natural gas hydrates to disassociate said natural gas hydrates in order to recover said natural gas and the water from said disassociation of said natural gas hydrates, said natural gas and said water migrating from said deposit of natural gas hydrates to an area of lower pressure being production casing.
2. A method as in claim 1 wherein a solvent is added to said water supplied to said deposit of said natural gas hydrates.
3. A method as in claim 1 wherein said heated water is injected into said deposit of said natural gas hydrates from a vertical, a deviated or a horizontal casing.
4. A method as in claim 2 wherein said solvent is methanol or ethylene glycol.
5. A method as in claim 1 wherein said water is heated by a reactor module located within a heating well having casing, said water supplied to said deposit of gas hydrates being heated by said reactor- module.
6. A method as in claim 5 wherein said reactor module further heats said casing of said heating well.
7. Apparatus for heating a deposit of gas hydrates to disassociate said gas hydrates and obtain natural gas comprising a reactor module located within casing of a heating well, a water injector to supply water to said reactor module and a heater within said reactor module to heat said water supplied to said reactor module and to inject said heated water into said deposit of gas hydrates.
8. Apparatus as in claim 7 and further comprising an injector for a solvent to be added to said water supplied to said reactor module.
9. Apparatus as in claim 8 wherein said reactor module provides heat by either induction or by resistive heating.
10. Method of heating a deposit of natural gas hydrates comprising positioning an induction tool in downhole well casing and generating an induction flux in said tool to excite and heat said well casing and said deposit of natural gas hydrates.
11. Method as in claim 10 wherein at least two induction tools are positioned in locations within said deposit of natural gas hydrates.
12. Apparatus as in claim 7 and further comprising a bladder to seal said reactor module within said well casing.
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/286,138 | 2005-11-23 | ||
US11/286,138 US20070114026A1 (en) | 2005-11-23 | 2005-11-23 | Method and apparatus for extracting gas hydrate deposits |
Publications (1)
Publication Number | Publication Date |
---|---|
CA2567413A1 true CA2567413A1 (en) | 2007-05-23 |
Family
ID=38052350
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
CA002567413A Abandoned CA2567413A1 (en) | 2005-11-23 | 2006-11-09 | Method and apparatus for extracting gas hydrate |
Country Status (2)
Country | Link |
---|---|
US (1) | US20070114026A1 (en) |
CA (1) | CA2567413A1 (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN115370325A (en) * | 2022-09-26 | 2022-11-22 | 中国科学院广州能源研究所 | System and method for exploiting marine natural gas hydrate resources |
Families Citing this family (13)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US7735554B2 (en) * | 2007-03-29 | 2010-06-15 | Texyn Hydrocarbon, Llc | System and method for recovery of fuel products from subterranean carbonaceous deposits via an electric device |
DE102010043720A1 (en) * | 2010-11-10 | 2012-05-10 | Siemens Aktiengesellschaft | System and method for extracting a gas from a gas hydrate occurrence |
WO2012134840A1 (en) * | 2011-03-29 | 2012-10-04 | Conocophillips Company | Subsea hydrocarbon recovery |
CN103254956B (en) * | 2013-05-06 | 2014-10-29 | 常州大学 | Device for recycling vent natural gas by hydrate method |
WO2015002544A2 (en) * | 2013-07-05 | 2015-01-08 | Energy Research Group As | Method and system for natural gas production |
US20150027697A1 (en) * | 2013-07-26 | 2015-01-29 | Baker Hughes Incorporated | System and method for producing methane from a methane hydrate formation |
WO2015047746A2 (en) * | 2013-09-30 | 2015-04-02 | Chevron U.S.A. Inc. | Natural gas hydrate reservoir heating |
CN104499971A (en) * | 2014-10-22 | 2015-04-08 | 中国石油天然气股份有限公司 | Method for breaking down natural gas well |
JP6016173B2 (en) * | 2014-10-23 | 2016-10-26 | 百代 結城 | Methane hydrate collection method using horizontal well and quicklime |
CN107420069B (en) * | 2017-07-13 | 2019-04-16 | 大连理工大学 | A kind of gas hydrates occurrence type simulation extracting experiment system |
CN108005626B (en) * | 2017-11-27 | 2020-11-24 | 华南理工大学 | Natural gas hydrate exploitation device and method based on heat pipe technology |
CN110344801B (en) * | 2018-04-03 | 2021-05-25 | 威海海冰能源科技有限公司 | Fracturing operation method for combustible ice exploitation, exploitation method and exploitation system |
CN109633754B (en) * | 2018-12-29 | 2021-05-28 | 中国地质调查局油气资源调查中心 | Simulation method of natural gas hydrate development simulation experiment device |
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Publication number | Priority date | Publication date | Assignee | Title |
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US2781851A (en) * | 1954-10-11 | 1957-02-19 | Shell Dev | Well tubing heater system |
US3916993A (en) * | 1974-06-24 | 1975-11-04 | Atlantic Richfield Co | Method of producing natural gas from a subterranean formation |
US4007787A (en) * | 1975-08-18 | 1977-02-15 | Phillips Petroleum Company | Gas recovery from hydrate reservoirs |
US4456068A (en) * | 1980-10-07 | 1984-06-26 | Foster-Miller Associates, Inc. | Process and apparatus for thermal enhancement |
US5420402A (en) * | 1992-02-05 | 1995-05-30 | Iit Research Institute | Methods and apparatus to confine earth currents for recovery of subsurface volatiles and semi-volatiles |
US5619611A (en) * | 1995-12-12 | 1997-04-08 | Tub Tauch-Und Baggertechnik Gmbh | Device for removing downhole deposits utilizing tubular housing and passing electric current through fluid heating medium contained therein |
FR2763992B1 (en) * | 1997-05-30 | 1999-08-20 | Drillflex | PROCESS AND DEVICE FOR CLOSING A WELL OR PIPE OBSTRUCTED BY GAS HYDRATES |
US6353706B1 (en) * | 1999-11-18 | 2002-03-05 | Uentech International Corporation | Optimum oil-well casing heating |
CA2375565C (en) * | 2002-03-08 | 2004-06-22 | Rodney T. Beida | Wellhead heating apparatus and method |
US6973968B2 (en) * | 2003-07-22 | 2005-12-13 | Precision Combustion, Inc. | Method of natural gas production |
US6978837B2 (en) * | 2003-11-13 | 2005-12-27 | Yemington Charles R | Production of natural gas from hydrates |
US7198107B2 (en) * | 2004-05-14 | 2007-04-03 | James Q. Maguire | In-situ method of producing oil shale and gas (methane) hydrates, on-shore and off-shore |
US7784545B2 (en) * | 2004-05-14 | 2010-08-31 | Maguire James Q | In-situ method of fracturing gas shale and geothermal areas |
-
2005
- 2005-11-23 US US11/286,138 patent/US20070114026A1/en not_active Abandoned
-
2006
- 2006-11-09 CA CA002567413A patent/CA2567413A1/en not_active Abandoned
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN115370325A (en) * | 2022-09-26 | 2022-11-22 | 中国科学院广州能源研究所 | System and method for exploiting marine natural gas hydrate resources |
CN115370325B (en) * | 2022-09-26 | 2023-06-09 | 中国科学院广州能源研究所 | System and method for exploiting marine natural gas hydrate resources |
Also Published As
Publication number | Publication date |
---|---|
US20070114026A1 (en) | 2007-05-24 |
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