US20130312976A1 - Methods for using liquefied natural gas for well stimulation - Google Patents
Methods for using liquefied natural gas for well stimulation Download PDFInfo
- Publication number
- US20130312976A1 US20130312976A1 US13/897,699 US201313897699A US2013312976A1 US 20130312976 A1 US20130312976 A1 US 20130312976A1 US 201313897699 A US201313897699 A US 201313897699A US 2013312976 A1 US2013312976 A1 US 2013312976A1
- Authority
- US
- United States
- Prior art keywords
- foam
- well
- dense fluid
- natural gas
- fed
- 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 30
- 239000003949 liquefied natural gas Substances 0.000 title claims abstract description 18
- 230000000638 stimulation Effects 0.000 title 1
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims abstract description 76
- 239000012530 fluid Substances 0.000 claims abstract description 62
- 239000006260 foam Substances 0.000 claims abstract description 42
- 239000003345 natural gas Substances 0.000 claims abstract description 32
- 239000007789 gas Substances 0.000 claims abstract description 17
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 8
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 7
- 230000008016 vaporization Effects 0.000 claims description 7
- 238000002347 injection Methods 0.000 claims description 6
- 239000007924 injection Substances 0.000 claims description 6
- 229930014626 natural product Natural products 0.000 claims description 6
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 4
- 239000001569 carbon dioxide Substances 0.000 claims description 4
- 238000002485 combustion reaction Methods 0.000 claims description 4
- 229910052757 nitrogen Inorganic materials 0.000 claims description 3
- 239000003129 oil well Substances 0.000 claims description 3
- 238000003860 storage Methods 0.000 claims description 3
- 239000006200 vaporizer Substances 0.000 claims description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 7
- 239000000203 mixture Substances 0.000 description 4
- 230000015572 biosynthetic process Effects 0.000 description 2
- 238000005755 formation reaction Methods 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 239000003915 liquefied petroleum gas Substances 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 239000011435 rock Substances 0.000 description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 229910010293 ceramic material Inorganic materials 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 230000005611 electricity Effects 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 239000011261 inert gas Substances 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000011707 mineral Chemical class 0.000 description 1
- JCXJVPUVTGWSNB-UHFFFAOYSA-N nitrogen dioxide Inorganic materials O=[N]=O JCXJVPUVTGWSNB-UHFFFAOYSA-N 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 238000000746 purification Methods 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- 230000004936 stimulating effect Effects 0.000 description 1
- 239000002352 surface water Substances 0.000 description 1
- 238000009834 vaporization Methods 0.000 description 1
- 239000003643 water by type 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
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
-
- 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
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/2605—Methods for stimulating production by forming crevices or fractures using gas or liquefied gas
Definitions
- the invention relates to a method for stimulating oil wells with liquefied natural gas. More particularly, the invention provides for injecting natural gas into an oil or gas well to fracture the well and to assist in recovering the natural gas present in the well.
- hydraulic fracturing In the production of natural gas from shale or other “tight-gas” formations, hydraulic fracturing (or “frac”) is used to break up the rock around the well bore and reduce the resistance to gas flow.
- the frac technique generally requires injecting into the well large amounts of fluids that are compressible like nitrogen or carbon dioxide or incompressible such as water or liquefied petroleum gas.
- the fluids are pumped to high pressure to create large compressive forces around the well bore. These forces break the rock and create tiny fissures for gas flow.
- small amounts on the order of 1 to 2% by volume of hydrocarbons mineral acids and “proppants” are added to the injected fluid.
- Thousands of tons of fluid may be injected during each frac job and much of this fluid is returned to the surface when the flow is reversed (hereafter called “produced fluids”) and natural gas is produced from the well.
- the produced fluid water is typically brackish with small amounts of the other materials injected into the formation. Reuse of these waters is problematic because of their composition and consequently, the produced fluid water must be treated for environmental concerns and disposed of in surface waters. Alternatively, the produced fluid water must be injected into deep saline aquifers. If gases or condensable hydrocarbons such as liquefied petroleum gas are used, their availability and disposal after use can also create difficulties for the producer.
- the invention addresses the problems associated with the disposal of producing fluid by using liquefied natural gas (LNG) as a fluid source.
- LNG liquefied natural gas
- the produced fluid will have roughly the same composition of natural gas and can be introduced into a pipeline without further processing.
- the invention provides for a method for fracturing an oil or gas well to recover natural gas.
- a) Vaporizing liquefied natural gas to form a foam or dense fluid; b) Compressing the foam or dense fluid and injecting into the well; c) Stopping the injection of the foam or dense fluid once a pre-determined pressure of the well has been reached; and d) Recovering the foam or dense fluid natural gas and product natural gas.
- a) Providing liquefied natural gas to a well site; b) Vaporizing liquefied natural gas to form a foam or dense fluid; c) Compressing the foam or dense fluid and injecting into the well; d) Stopping the injection of the foam or dense fluid once a pre-determined pressurization of the well has been reached; and e) Recovering the foam or dense fluid natural gas and product natural gas.
- the present invention provides for a method for fraccing an oil or gas well to recover natural gas.
- Liquefied natural gas is shipped to the well site in large quantities such as about 1000 tons.
- the liquefied natural gas is rapidly vaporized utilizing a high-speed vaporization technique such as by a submersible combustion vaporizer or other known technique to form a foam or dense fluid.
- the vaporized liquefied natural gas which is essentially methane gas may be mixed with small amounts of additives such as a proppant.
- the proppant is any that may be typically used in fracturing such as treated sand or a man-made ceramic material.
- the foam or dense fluid is then compressed by conventional techniques to pressures between 1000 and 10,000 pounds per square inch (psi) for injection into the well at rates ranging from 10,000 to 1,00,000 standard cubic feed (scf) per minute.
- carbon dioxide or nitrogen may be added to the liquefied natural gas prior to it being vaporized or before it is compressed for injection into the well such that the foam or dense fluid comprises more than just natural gas or natural gas plus one or more proppants.
- the flow of the pressurized natural gas is stopped.
- the foam or dense fluid will remain in the well for a time period necessary to assist in fracturing the well.
- the equipment that is employed to fed the foam or dense fluid is then reversed.
- the methane gas which is recovered is both the pressurized foam or dense fluid and methane present in the fractured well. This methane gas regardless of its origination is separated from the other produced fluids and proppants that may be recovered.
- the recovered methane gas whether it is from the foam or dense fluid used as the fracturing fluid or from the well proper can be fed directly to a pipeline where the methane can be sent to a storage facility or fed to another industrial operation.
- the recovered natural gas can be combusted and the combustion products run through heat exchangers, expanders or turbines to produce steam and/or electricity.
- the methods of the present invention using natural gas from liquefied natural gas have numerous advantages over water or inert gas as fracturing fluids.
- Large amounts of water-based fracturing fluids can remain in the reservoir and reduce natural gas flow from the well.
- the vaporized liquefied natural gas used as a foam or a dense fluid is essentially the same composition as the in-situ natural gas present in the well.
- the produced fluids can be treated by the same equipment and in the same manner as the produced natural gas without having to perform any separation or purification steps as an operator would have to if other fracturing fluids are used. Further, no additional safety issues are created when the vaporized liquefied natural gas is fed into well as a foam or dense fluid.
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)
- Filling Or Discharging Of Gas Storage Vessels (AREA)
- Separation By Low-Temperature Treatments (AREA)
Abstract
A method for fraccing oil or gas wells to recover natural gas. Liquefied natural gas is vaporized to form a foam or dense fluid. The foam or dense fluid is compressed to high pressures. The high pressure natural gas foam or dense fluid is fed into the oil or gas well and once the well is pressurized to a pre-determined pressure and fracturing has begun, the flow of the foam or dense fluid is stopped. After a suitable period for fracturing to occur, the flow is reversed and the natural gas from the well and the foam or dense fluid fracturing fluid is recovered. The recovered and produced natural gas can be treated and made ready for use in other applications.
Description
- This application claims priority from U.S. provisional application Ser. No. 61/650,588 file May 23, 2012.
- The invention relates to a method for stimulating oil wells with liquefied natural gas. More particularly, the invention provides for injecting natural gas into an oil or gas well to fracture the well and to assist in recovering the natural gas present in the well.
- In the production of natural gas from shale or other “tight-gas” formations, hydraulic fracturing (or “frac”) is used to break up the rock around the well bore and reduce the resistance to gas flow. The frac technique generally requires injecting into the well large amounts of fluids that are compressible like nitrogen or carbon dioxide or incompressible such as water or liquefied petroleum gas. The fluids are pumped to high pressure to create large compressive forces around the well bore. These forces break the rock and create tiny fissures for gas flow. To aid in the penetration and stability of theses fissures, small amounts on the order of 1 to 2% by volume of hydrocarbons, mineral acids and “proppants” are added to the injected fluid. Thousands of tons of fluid may be injected during each frac job and much of this fluid is returned to the surface when the flow is reversed (hereafter called “produced fluids”) and natural gas is produced from the well.
- If water is used as the fracturing fluid, the produced fluid water is typically brackish with small amounts of the other materials injected into the formation. Reuse of these waters is problematic because of their composition and consequently, the produced fluid water must be treated for environmental concerns and disposed of in surface waters. Alternatively, the produced fluid water must be injected into deep saline aquifers. If gases or condensable hydrocarbons such as liquefied petroleum gas are used, their availability and disposal after use can also create difficulties for the producer.
- The invention addresses the problems associated with the disposal of producing fluid by using liquefied natural gas (LNG) as a fluid source. The produced fluid will have roughly the same composition of natural gas and can be introduced into a pipeline without further processing.
- To address these concerns, the invention provides for a method for fracturing an oil or gas well to recover natural gas.
- In one embodiment of the invention, there is disclosed a method for fracturing a well comprising the steps:
- a) Vaporizing liquefied natural gas to form a foam or dense fluid;
b) Compressing the foam or dense fluid and injecting into the well;
c) Stopping the injection of the foam or dense fluid once a pre-determined pressure of the well has been reached; and
d) Recovering the foam or dense fluid natural gas and product natural gas. - In another embodiment of the invention there is disclosed a method for fracturing a well comprising the steps:
- a) Providing liquefied natural gas to a well site;
b) Vaporizing liquefied natural gas to form a foam or dense fluid;
c) Compressing the foam or dense fluid and injecting into the well;
d) Stopping the injection of the foam or dense fluid once a pre-determined pressurization of the well has been reached; and
e) Recovering the foam or dense fluid natural gas and product natural gas. - The present invention provides for a method for fraccing an oil or gas well to recover natural gas. Liquefied natural gas is shipped to the well site in large quantities such as about 1000 tons. The liquefied natural gas is rapidly vaporized utilizing a high-speed vaporization technique such as by a submersible combustion vaporizer or other known technique to form a foam or dense fluid. The vaporized liquefied natural gas which is essentially methane gas may be mixed with small amounts of additives such as a proppant. The proppant is any that may be typically used in fracturing such as treated sand or a man-made ceramic material.
- The foam or dense fluid is then compressed by conventional techniques to pressures between 1000 and 10,000 pounds per square inch (psi) for injection into the well at rates ranging from 10,000 to 1,00,000 standard cubic feed (scf) per minute.
- Depending upon the nature of the well and the composition of natural gas present in the well, carbon dioxide or nitrogen may be added to the liquefied natural gas prior to it being vaporized or before it is compressed for injection into the well such that the foam or dense fluid comprises more than just natural gas or natural gas plus one or more proppants.
- Once the well has been fully pressurized to a pressure pre-determined by the operator and the fracturing process initiated, the flow of the pressurized natural gas is stopped. The foam or dense fluid will remain in the well for a time period necessary to assist in fracturing the well. The equipment that is employed to fed the foam or dense fluid is then reversed. The methane gas which is recovered is both the pressurized foam or dense fluid and methane present in the fractured well. This methane gas regardless of its origination is separated from the other produced fluids and proppants that may be recovered. The recovered methane gas whether it is from the foam or dense fluid used as the fracturing fluid or from the well proper can be fed directly to a pipeline where the methane can be sent to a storage facility or fed to another industrial operation. Alternatively, the recovered natural gas can be combusted and the combustion products run through heat exchangers, expanders or turbines to produce steam and/or electricity.
- The methods of the present invention using natural gas from liquefied natural gas have numerous advantages over water or inert gas as fracturing fluids. Large amounts of water-based fracturing fluids, for example, can remain in the reservoir and reduce natural gas flow from the well. The vaporized liquefied natural gas used as a foam or a dense fluid is essentially the same composition as the in-situ natural gas present in the well. When fracturing is completed and the flow of the feed equipment is reversed, the produced fluids can be treated by the same equipment and in the same manner as the produced natural gas without having to perform any separation or purification steps as an operator would have to if other fracturing fluids are used. Further, no additional safety issues are created when the vaporized liquefied natural gas is fed into well as a foam or dense fluid.
- While this invention has been described with respect to particular embodiments thereof, it is apparent that numerous other forms and modifications of the invention will be obvious to those skilled in the art. The appended claims in this invention generally should be construed to cover all such obvious forms and modifications which are within the true spirit and scope of the invention.
Claims (18)
1. A method for fracturing a well comprising the steps:
a) vaporizing liquefied natural gas to form a foam or dense fluid;
b) compressing the foam or dense fluid and injecting into the well;
c) stopping the injection of the foam or dense fluid once a pre-determined pressure of the well has been reached; and
d) recovering the foam or dense fluid natural gas and product natural gas.
2. The method as claimed in claim 1 wherein the well is selected from the group consisting of an oil well and a gas well.
3. The method as claimed in claim 1 wherein vaporizing is performed by a submersible combustion vaporizer.
4. The method as claimed in claim 1 wherein a proppant is added to the foam or dense fluid.
5. The method as claimed in claim 1 wherein the foam or dense fluid is compressed to pressures from 1000 to 10,000 pounds per square inch.
6. The method as claimed in claim 1 wherein the foam or dense fluid is fed into the well at rates from 10,000 to 1,000,000 standard cubic feet per minute.
7. The method as claimed in claim 1 wherein the pre-determined pressure is a pressure at which fracturing of the well will occur.
8. The method as claimed in claim 1 further comprising adding to the foam or dense fluid a gas selected from the group consisting of carbon dioxide and nitrogen.
9. The method as claimed in claim 1 wherein the recovered foam or dense fluid natural gas and product natural gas is fed to storage, fed to another industrial operation, combusted or reused as the foam or dense fluid being fed to the well.
10. A method for fracturing a well comprising the steps:
a) providing liquefied natural gas to a well site;
b) vaporizing liquefied natural gas to form a foam or dense fluid;
c) compressing the foam or dense fluid and injecting into the well;
d) stopping the injection of the foam or dense fluid once a pre-determined pressurization of the well has been reached; and
e) recovering the foam or dense fluid natural gas and product natural gas.
11. The method as claimed in claim 10 wherein vaporizing is performed by a submersible combustion vaporizer.
12. The method as claimed in claim 10 wherein the well is selected from the group consisting of gas and oil wells.
13. The method as claimed in claim 10 wherein a proppant is added to the foam or dense fluid.
14. The method as claimed in claim 10 wherein the foam or dense fluid is compressed to pressures from 1000 to 10,000 pounds per square inch.
15. The method as claimed in claim 10 wherein the foam or dense fluid is fed into the well at rates from 10,000 to 1,000,000 standard cubic feet per minute.
16. The method as claimed in claim 10 wherein the pre-determined pressure is a pressure at which fracturing of the well will occur.
17. The method as claimed in claim 10 further comprising adding to the foam or dense fluid a gas selected from the group consisting of carbon dioxide and nitrogen.
18. The method as claimed in claim 10 wherein the recovered foam or dense fluid natural gas and product natural gas is fed to storage, fed to another industrial operation, combusted or reused as the foam or dense fluid being fed to the well.
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/897,699 US20130312976A1 (en) | 2012-05-23 | 2013-05-20 | Methods for using liquefied natural gas for well stimulation |
PCT/US2013/041952 WO2013177114A1 (en) | 2012-05-23 | 2013-05-21 | Methods for using liquefied natural gas for well stimulation |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US201261650588P | 2012-05-23 | 2012-05-23 | |
US13/897,699 US20130312976A1 (en) | 2012-05-23 | 2013-05-20 | Methods for using liquefied natural gas for well stimulation |
Publications (1)
Publication Number | Publication Date |
---|---|
US20130312976A1 true US20130312976A1 (en) | 2013-11-28 |
Family
ID=47520838
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US13/897,699 Abandoned US20130312976A1 (en) | 2012-05-23 | 2013-05-20 | Methods for using liquefied natural gas for well stimulation |
Country Status (3)
Country | Link |
---|---|
US (1) | US20130312976A1 (en) |
EP (1) | EP2666958A1 (en) |
WO (1) | WO2013177114A1 (en) |
Cited By (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20140262285A1 (en) * | 2013-03-12 | 2014-09-18 | Rustam H. Sethna | Methods for fraccing oil and gas wells |
WO2018089021A1 (en) * | 2016-11-11 | 2018-05-17 | Halliburton Energy Services, Inc. | Liquefied natural gas (lng) re-fracturing |
WO2019022763A1 (en) * | 2017-07-28 | 2019-01-31 | Halliburton Energy Services, Inc. | Acidizing and interfacial tension reducing hydrolysable oils for subterranean treatments |
US10344204B2 (en) | 2015-04-09 | 2019-07-09 | Diversion Technologies, LLC | Gas diverter for well and reservoir stimulation |
US10385258B2 (en) | 2015-04-09 | 2019-08-20 | Highlands Natural Resources, Plc | Gas diverter for well and reservoir stimulation |
US10982520B2 (en) | 2016-04-27 | 2021-04-20 | Highland Natural Resources, PLC | Gas diverter for well and reservoir stimulation |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN112832728B (en) * | 2021-01-08 | 2022-03-18 | 中国矿业大学 | Shale reservoir fracturing method based on methane multistage combustion and explosion |
Citations (4)
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US20090277219A1 (en) * | 2004-12-16 | 2009-11-12 | Fluor Technologies Corporation | Configurations and Methods for Offshore LNG Regasification and BTU Control |
US20120118566A1 (en) * | 2012-01-26 | 2012-05-17 | Expansion Energy, Llc | Non-hydraulic fracturing systems, methods, and processes |
WO2012097426A1 (en) * | 2011-01-17 | 2012-07-26 | Enfrac Inc. | Fracturing system and method for an underground formation using natural gas and an inert purging fluid |
WO2013163476A1 (en) * | 2012-04-25 | 2013-10-31 | Anderson Kenneth W | Systems and methods for converting liquid natural gas to compressed natural gas and to low pressure natural gas |
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US5711376A (en) * | 1995-12-07 | 1998-01-27 | Marathon Oil Company | Hydraulic fracturing process |
US20060065400A1 (en) * | 2004-09-30 | 2006-03-30 | Smith David R | Method and apparatus for stimulating a subterranean formation using liquefied natural gas |
US8356487B2 (en) * | 2007-09-07 | 2013-01-22 | SPX Cooling Technologies | Control system and method for vaporizer with heating tower |
DE102009007453B4 (en) | 2009-02-04 | 2011-02-17 | Leibniz-Institut für Meereswissenschaften | Process for natural gas production from hydrocarbon hydrates with simultaneous storage of carbon dioxide in geological formations |
US8846585B2 (en) * | 2010-09-17 | 2014-09-30 | Clearwater International, Llc | Defoamer formulation and methods for making and using same |
-
2013
- 2013-01-07 EP EP13150380.7A patent/EP2666958A1/en not_active Withdrawn
- 2013-05-20 US US13/897,699 patent/US20130312976A1/en not_active Abandoned
- 2013-05-21 WO PCT/US2013/041952 patent/WO2013177114A1/en active Application Filing
Patent Citations (4)
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US20090277219A1 (en) * | 2004-12-16 | 2009-11-12 | Fluor Technologies Corporation | Configurations and Methods for Offshore LNG Regasification and BTU Control |
WO2012097426A1 (en) * | 2011-01-17 | 2012-07-26 | Enfrac Inc. | Fracturing system and method for an underground formation using natural gas and an inert purging fluid |
US20120118566A1 (en) * | 2012-01-26 | 2012-05-17 | Expansion Energy, Llc | Non-hydraulic fracturing systems, methods, and processes |
WO2013163476A1 (en) * | 2012-04-25 | 2013-10-31 | Anderson Kenneth W | Systems and methods for converting liquid natural gas to compressed natural gas and to low pressure natural gas |
Non-Patent Citations (1)
Title |
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Campbell, John M., Variation of properties in the dense phase region; Part 2 - Natural Gas, January 1, 2010, PetroSkills, available at "http://www.jmcampbell.com/tip-of-the-month/2010/01/variation-of-properties-in-the-dense-phase-region-part-2-%E2%80%93-natural-gas/" * |
Cited By (9)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20140262285A1 (en) * | 2013-03-12 | 2014-09-18 | Rustam H. Sethna | Methods for fraccing oil and gas wells |
US10344204B2 (en) | 2015-04-09 | 2019-07-09 | Diversion Technologies, LLC | Gas diverter for well and reservoir stimulation |
US10385258B2 (en) | 2015-04-09 | 2019-08-20 | Highlands Natural Resources, Plc | Gas diverter for well and reservoir stimulation |
US10385257B2 (en) | 2015-04-09 | 2019-08-20 | Highands Natural Resources, PLC | Gas diverter for well and reservoir stimulation |
US10982520B2 (en) | 2016-04-27 | 2021-04-20 | Highland Natural Resources, PLC | Gas diverter for well and reservoir stimulation |
WO2018089021A1 (en) * | 2016-11-11 | 2018-05-17 | Halliburton Energy Services, Inc. | Liquefied natural gas (lng) re-fracturing |
US11506037B2 (en) | 2016-11-11 | 2022-11-22 | Halliburton Energy Services, Inc. | Liquefied natural gas (LNG) re-fracturing |
WO2019022763A1 (en) * | 2017-07-28 | 2019-01-31 | Halliburton Energy Services, Inc. | Acidizing and interfacial tension reducing hydrolysable oils for subterranean treatments |
US11390798B2 (en) | 2017-07-28 | 2022-07-19 | Hallburton Energy Services, Inc. | Acidizing and interfacial tension reducing hydrolysable oils for subterranean treatments |
Also Published As
Publication number | Publication date |
---|---|
EP2666958A1 (en) | 2013-11-27 |
WO2013177114A1 (en) | 2013-11-28 |
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