WO2007039443A1 - Procédé de production d’un flux d'hydrocarbure à partir d'une zone souterraine - Google Patents

Procédé de production d’un flux d'hydrocarbure à partir d'une zone souterraine Download PDF

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Publication number
WO2007039443A1
WO2007039443A1 PCT/EP2006/066473 EP2006066473W WO2007039443A1 WO 2007039443 A1 WO2007039443 A1 WO 2007039443A1 EP 2006066473 W EP2006066473 W EP 2006066473W WO 2007039443 A1 WO2007039443 A1 WO 2007039443A1
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WO
WIPO (PCT)
Prior art keywords
mol
injection fluid
synthesis gas
containing stream
gasification reactor
Prior art date
Application number
PCT/EP2006/066473
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English (en)
Inventor
Hendrik Jan Van Der Ploeg
Thian Hoey Tio
Pieter Lammert Zuideveld
Original Assignee
Shell Internationale Research Maatschappij B.V.
Shell Canada Limited
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Shell Internationale Research Maatschappij B.V., Shell Canada Limited filed Critical Shell Internationale Research Maatschappij B.V.
Priority to EP06793611A priority Critical patent/EP1926885A1/fr
Priority to CN200680034679.XA priority patent/CN101268250B/zh
Priority to CA2620734A priority patent/CA2620734C/fr
Priority to JP2008530547A priority patent/JP5468260B2/ja
Publication of WO2007039443A1 publication Critical patent/WO2007039443A1/fr

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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
    • E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
    • E21B43/168—Injecting a gaseous medium

Definitions

  • the present invention relates to a method of producing a hydrocarbon containing stream from a subterranean zone wherein an injection fluid is injected into the subterranean zone. It is known to inject an injection fluid into a subterranean zone such as an oil or gas field in order to maintain a desired pressure therein to improve the production of the desired hydrocarbon stream from the subterranean zone.
  • a subterranean zone such as an oil or gas field
  • injection fluids that have been proposed to inject in an oil field for EOR are a.o. natural gas (NG), carbon dioxide (CO2) and nitrogen (N2) •
  • NG natural gas
  • CO2 carbon dioxide
  • N2 nitrogen
  • the injection of injection fluids such as NG, CO2 and N2 in an oil field has been described in e.g. ⁇ World' s Largest ⁇ -generation Plant, Commissioned for Cantarell Pressure Maintenance>>, J. C. Kuo, Doug Elliot, Javier Luna-Melo, Jose B. De Leon Perez, published in Oil & Gas Journal, March 12, 2001.
  • Other publications which describe the use of such injection fluids are for example CA-A-2147079, CA-A-2261517, CA-A-2163684 and US-A-4161047.
  • a further problem is that the known injection fluids are often available at low pressures and as a result a compression step is necessary before injection into the oil field, leading to additional costs.
  • US-A-4512400 describes a process to make a LPG type injection fluid from natural gas.
  • natural gas is first converted into a mixture of carbon monoxide and hydrogen and secondly this gas mixture is used as feed in a Fischer-Tropsch synthesis.
  • an ethane, propane and butane containing gas i.e. the LPG type gas, is isolated and used as injection fluid.
  • EP-A-1004746 describes a process for performing an enhanced oil recovery by partial oxidation of an associated gas into a mixture of carbon monoxide and hydrogen. This mixture is used as feed in a Fischer- Tropsch synthesis to obtain a liquid hydrocarbon product and an off-gas.
  • This off-gas will contain nitrogen, carbon monoxide, carbon dioxide, hydrogen and C1-C5 hydrocarbons.
  • This off-gas is used as fuel to generate energy in an expanding/combustion process, e.g. a combined gas turbine/steam turbine cycle. The energy generated is in turn used for the secondary and/or enhanced recovery of oil from a subsurface reservoir.
  • a disadvantage of the process of US-A-4512400 and EP-A-1004746 is that a Fischer-Tropsch process step is part of the method. Such a process step makes the method complex .
  • a disadvantage of using a flue gas is that the oxygen content of the directly obtained flue gas is about 3.5 vol%, which is too high for direct use as injection fluid. Special measures have to be taken to lower the oxygen content .
  • a subterranean zone such as an oil or gas field.
  • a further advantage of the present invention is that the injection fluid will be substantially free of free oxygen (O 2 ) , as a result of the presence of the synthesis gas.
  • the hydrocarbon stream to be produced from the subterranean zone may have various compositions, but will usually be natural gas, gas condensate, oil, also referred to as crude mineral oil, or a mixture thereof.
  • the subterranean zone may be any subterranean zone comprising hydrocarbons to be harvested. Examples of a subterranean zone are e.g. an oil field, gas field, etc. It goes without saying that the subterranean zone may also be located underwater or the like.
  • the injection fluid may be produced in various manners, e.g. by catalytic or non-catalytic partial oxidation or by any other way, provided that it comprises synthesis gas (i.e. carbon monoxide (CO) and hydrogen (H 2 )).
  • synthesis gas i.e. carbon monoxide (CO) and hydrogen (H 2 )
  • the injection of an injection fluid and the associated production of the hydrocarbon stream from the subterranean zone is known as such and for example described in the references discussed in the introductory part of this disclosure.
  • the desired pressure to be obtained in the subterranean zone will depend on the circumstances and can be readily determined by the person skilled in the art. Usually, it is desired to maintain the existing pressure in the subterranean zone; therefore, the term "obtaining a desired pressure" also includes maintaining a certain pressure in the subterranean zone.
  • the injection fluid comprises from 0.1 to 20 mol% synthesis gas (i.e. CO + H 2 ) based on dry gas, preferably > 3 mol% and ⁇ 10 mol%, more preferably about 5 mol%.
  • synthesis gas i.e. CO + H 2
  • the injection fluid comprises, based on dry gas:
  • the injection fluid provided in step (a) is substantially free of O2, preferably comprising less than 10 ppmv.
  • the injection fluid at injection has a pressure in the range from 50 to 500 bar, preferably > 70 bar and ⁇ 400 bar, more preferably > 80 bar and ⁇ 300 bar; and a temperature in the range from 0 to 300 0 C, preferably > 20 0 C and ⁇ 100 0 C.
  • the injection fluid is preferably made from a hydrocarbon stream.
  • This hydrocarbon stream may be isolated from the hydrocarbon stream to be produced from the subterranean zone. Alternatively this hydrocarbon stream may be derived from another source. In order to avoid any confusion this hydrocarbon stream is further referred to as the carbonaceous synthesis gas source.
  • the synthesis gas may in general be made from one or more carbonaceous synthesis gas sources using one or more conversion processes. Examples of suitable carbonaceous synthesis gas sources are natural gas, LPG, coal, brown coal, peat, wood, coke, soot, biomass, oil, condensate or any other gaseous, liquid or solid fuel or mixture thereof. Preferred carbonaceous synthesis gas sources are part of the hydrocarbon containing stream produced from the subterranean zone.
  • Examples of such sources are natural gas when producing a natural gas hydrocarbon and more especially associated gas when producing a crude oil hydrocarbon.
  • the preferred conversion processes are steam reforming, suitably auto thermal steam reforming (ATR) , catalytic partial oxidation and preferably by a partial oxidation process, more preferably by a non-catalytic partial oxidation process.
  • ATR auto thermal steam reforming
  • the non-gaseous carbonaceous sources like for example coal, peat, wood, petroleum coke, soot, biomass, oil, de-asphalted oil, cracked vacuum residue and gas condensate, are preferably converted to synthesis gas by means of a partial oxidation process.
  • the partial oxidation may be performed in one or more partial oxidation steps in order to increase the volume percentage of nitrogen and carbon dioxide relative to the amount of carbonaceous synthesis gas source used.
  • the present invention provides a method of producing an injection fluid, the method at least comprising: (al) providing a synthesis gas containing stream; and
  • step (a2) partially oxidising the synthesis gas containing stream provided in step (al), thereby obtaining an injection fluid comprising synthesis gas.
  • step (a2) is available at relatively high pressures such that the stream obtained has a pressure suitable to be injected directly or after further compression in an oil field or other subterranean zone.
  • the stream obtained in step (a2) is available at relatively high pressures such that the stream obtained has a pressure suitable to be injected directly or after further compression in an oil field or other subterranean zone.
  • the synthesis gas containing stream provided in step (al) may be a partially oxidised stream, but may also be obtained in any other suitable way.
  • the ⁇ synthesis gas containing stream' provided in step (al) contains more synthesis gas (preferably > 25 mol%, based on dry gas) than the ⁇ injection fluid' obtained in step (a2) (preferably from 0.1 to 20 mol% based on dry gas) . If desired more than two partial oxidation steps may take place, if desired.
  • the synthesis gas containing stream provided in step (al) may be obtained from a carbonaceous synthesis gas source as described above.
  • the synthesis gas containing stream provided in step (al) is obtained by partial combustion, i.e. partially oxidising a hydrocarbon stream, preferably selected from the group consisting of oil, gas and coal, more preferably gas.
  • a hydrocarbon stream preferably selected from the group consisting of oil, gas and coal, more preferably gas.
  • the latter is frequently available at an oil field, in the form of associated gas, in which the injection fluid is to be injected for producing oil.
  • an advantage of using natural gas or associated gas as feed for step (al) is that these feeds are obtained from the subsurface reservoir at high pressures. This allows this feed to be used without less or no compression as feed to the partial oxidation as performed at elevated pressure.
  • the synthesis gas containing stream provided in step (al) comprises > 25 mol% synthesis gas based on dry gas, preferably from 30 to 50 mol%, more preferably from 30 to 40 mol%.
  • the synthesis gas containing stream provided in step (al) has a pressure in the range from 20 to 200 bar, preferably > 40 bar and ⁇ 100 bar; and a temperature in the range from 100 to 400 0 C, preferably > 200 0 C and ⁇ 350 0 C.
  • the synthesis gas containing stream provided in step (al) is also obtained by partially oxidising a hydrocarbon stream.
  • the partial oxidation in both steps (al) and (a2) are obtained by non-catalytic partial oxidation, i.e. partial combustion.
  • the advantage of more than one partial oxidation step to obtain the injection fluid (compared to one partial oxidation step) is that the temperature of the process can be better controlled.
  • the synthesis gas containing stream obtained in step (al) may be cooled before partially oxidising it in step (a2) .
  • any free O 2 containing stream may be used.
  • step (a2) preferably air or oxygen- enriched air is used, preferably containing at least 70% N 2 .
  • step (a2) is performed by recycling part of the synthesis gas containing stream obtained in step (al) back to step
  • step (al) Preferably the recycle synthesis gas is reduced in temperature before being recycled. Preferably 1 to 20 mol% is recycled to step (al), wherein the recycle is calculated as the mol fraction recycle stream on the total injection fluid prepared by the process times 100%.
  • the injection fluid obtained in step (a2) or in case of a recycle embodiment in the combined steps (al) and (a2) has a pressure in the range from 20 to 200 bar, preferably > 50 bar and ⁇ 80 bar; and is cooled to a temperature in the range from 0 to 300 0 C, preferably > 20 0 C and ⁇ 100 0 C.
  • the injection fluid may be compressed before injection to a pressure in the range of from 50 to 500 bar.
  • the injection fluid obtained in step (a2) is substantially free of O 2 , preferably comprising less than 10 ppmv.
  • the injection fluid obtained in step (a2) comprises from 0.1 to 20 mol% synthesis gas based on dry gas, preferably > 3 mol% and ⁇ 10 mol%, more preferably about 5 mol%; even more preferably the injection fluid obtained in step (a2) comprises, based on dry gas :
  • - from 0.1 to 20 mol% synthesis gas preferably > 3 mol% and ⁇ 10 mol%, more preferably about 5 mol%;
  • - from 5 to 20 mol% CO 2 preferably from 10 to 20 mol% and even more preferably from 12 to 15 mol%;
  • the injection fluid obtained in step (a2) may be further processed before injection into an oil field or other subterranean zone, without substantially changing the amount of synthesis gas being present.
  • the injection fluid obtained in step (a2) may be cooled, freed from any H2O being present and compressed.
  • the present invention provides an injection fluid obtainable by the method according to the present invention, preferably comprising, based on dry gas: - from 0.1 to 20 mol% synthesis gas, preferably
  • the injection fluid is substantially free of O 2 , preferably comprising less than 10 ppmv.
  • the present invention provides a system for producing an injection fluid for injection in a subterranean zone, the system at least comprising: a first gasification reactor having an inlet for an oxygen containing stream, an inlet for a hydrocarbon stream, and downstream of the first gasification reactor an outlet for a synthesis gas containing stream produced in the first gasification reactor; a second gasification reactor having an inlet for a second oxygen containing stream, an inlet being connected to the outlet of the first gasification reactor, and downstream of the second gasification reactor an outlet for an injection fluid produced in the second gasification reactor.
  • the system further comprises: a first cooler for cooling the synthesis gas containing stream produced in the first gasification reactor; and a second cooler for cooling the injection fluid produced in the second gasification reactor.
  • the first and second gasification reactors may be any suitable gasification reactor. As gasification reactors are known as such, they are not further discussed here. If desired more than one first and second gasification reactors may be used thereby obtaining a system comprising more than two gasification reactors.
  • the second gasification reactor is a gas gasification reactor in which partial oxidation of the gas can be performed. Examples of suitable gas gasifiers and coolers are described in US-A-4836831, EP-A-257719, EP-A-774103.
  • the first and second oxygen containing streams may be from any suitable source. Preferably substantially pure (> 95 mol%) oxygen or (optionally oxygen-enriched) air or the like is used in the first gasification reactor and (optionally oxygen-enriched) air in the second gasification reactor.
  • the present invention provides a system for producing an injection fluid for injection in a subterranean zone, the system at least comprising: a gasification reactor having an inlet for an oxygen containing stream, an inlet for a hydrocarbon stream, and downstream of the first gasification reactor an outlet for a synthesis gas containing stream produced in the gasification reactor; a cooler for cooling the synthesis gas containing stream produced in the first gasification reactor; and splitter to split the cooled synthesis gas into two streams, a conduit to recycle one synthesis stream to the gasification reactor and a conduit to discharge the injection fluid.
  • the gasification reactors may be any suitable gasification reactor. As gasification reactors are known as such, they are not further discussed here. If desired more than one gasification reactor may be used in parallel thereby obtaining a system comprising two or more gasification reactors.
  • the gasification reactor is a gas gasification reactor in which partial oxidation of the gas can be performed.
  • Figure 1 schematically shows a method of producing a hydrocarbon stream from a subterranean zone according to the present invention
  • Figure 2 schematically shows a process scheme for performing a method of producing an injection fluid according the present invention wherein two gasification reactors are used in series flow.
  • Figure 3 schematically shows a process scheme for performing a method of producing an injection fluid according the present invention wherein a recycle is applied.
  • Figure 1 schematically shows a method of producing oil 110 from a subterranean oil field 100 (under the surface 150 of the earth) wherein an injection fluid 50 is injected in or near the oil field 100.
  • the injection fluid 50 contains synthesis gas (CO + H 2 ), preferably 0.1 - 20 mol% based on dry gas.
  • the injection fluid 50 may have been obtained in various manners.
  • the injection fluid 50 is obtained by partial oxidation, e.g. in a system 1 comprising one or more gasification reactors.
  • the injection fluid 50 is injected using an injector 120 in the subterranean oil field 100, thereby obtaining or maintaining a desired pressure to enhance oil production from the oil field 100.
  • the injection fluid 50 is compressed (the compressed injection fluid is indicated as stream 51) before injecting into the oil field 100.
  • the compressed injection fluid is indicated as stream 51
  • an oil stream 110 is obtained and removed at the pumping unit 130 for further processing. More than one stream 110 may be obtained; also, other hydrocarbon streams such as natural gas may be produced.
  • Figure 2 schematically shows a system 1 for producing an injection fluid 50 containing synthesis gas to be injected in an oil field (not shown in Fig. 2; see Fig. 1) .
  • the system 1 comprises a first gasification reactor 2 and a second gasification reactor 3.
  • the first gasification reactor 2 is an oil gasification reactor and the second gasification reactor 3 is a gas gasification reactor.
  • the person skilled in the art will readily understand that the first gasification reactor 2 may also be a coal gasification reactor or a gasification reactor suitable for any other hydrocarbon containing stream.
  • an oil containing stream 10 and an oxygen containing stream 20 are fed at inlets 4 and 5, respectively, into the oil gasification reactor 2.
  • the oil containing stream 10 is partially oxidised by combustion in the gasification reactor 2 in a usual manner thereby obtaining a synthesis gas containing stream 30 (removed via outlet 6) and a slag 60 (removed via outlet 13) .
  • one or more burners (not shown) are present in the gasification reactor 2.
  • the synthesis gas containing stream 30 produced in the oil gasification reactor 2 usually comprises
  • the stream 30 has a pressure in the range from 20 to 200 bar; and has a temperature in the range from 1000 to 1500 0 C.
  • the stream 30 is cooled to a temperature in the range of 100-400 0 C in cooler 15, wherein the heat is used for e.g. steam generation.
  • the synthesis gas containing stream 30 is fed at inlet 7 into the second gasification reactor 3, being a gas gasification reactor. If desired, the synthesis gas containing stream 30 may be treated before entering the second gasification reactor 3, e.g. to remove any sulphur compounds being present.
  • the synthesis gas containing stream 30 is partially oxidised, preferably also by combustion, until only a small amount of synthesis gas (i.e. CO + H2) is left. If combustion is used for the partial oxidation in second gasification reactor 3, air or oxygen-enriched air is used, which is supplied at inlet 8 via stream 40.
  • Injection fluid 50 is obtained (which is removed via outlet 9) .
  • the injection fluid 50 obtained in the second gasification reactor 3 comprises from 0.1 to 20 mol% synthesis gas based on dry gas.
  • the synthesis gas containing stream 30 is a ⁇ partially oxidised stream' , it may also have been obtained in any other suitable way.
  • the ⁇ synthesis gas containing stream' provided in the first gasification reactor 2 (or ⁇ step (a)') contains more synthesis gas (viz. preferably
  • the injection fluid 50 obtained in the second gasification reactor 3 has a pressure in the range from 20 to 200 bar, preferably between 50 and 80 bar; has a temperature in the range from 0 to 300 0 C (after cooling in second cooler 25) ; and is substantially free of O 2 , preferably comprising less than 10 ppmv O 2 .
  • the resulting stream can be used as such as an injection fluid, with only a reduced amount of additional compression (e.g. in compressor 12 thereby obtaining stream 51) needed.
  • additional compression e.g. in compressor 12 thereby obtaining stream 51
  • the pressure of the stream 51 is in the range from 50 to 500 bar.
  • the additional compression may even be dispensed with.
  • any remaining free O 2 may be further removed, e.g. by catalytic oxidation using a suitable catalyst.
  • the injection fluid 50 may be further processed (such as cooling, H 2 O removal, etc.) before use as an injection fluid in an oil field or other subterranean zone.
  • the injection fluid 50 may be stored for later use.
  • Figure 3 shows another preferred embodiment of the present invention.
  • a methane containing gas 202 is partially oxidized with air 203 to obtain a synthesis gas containing stream 204.
  • This stream is cooled in a first step against evaporating water 206 to prepare high-pressure steam 207 in a boiler 205.
  • the cooled synthesis gas containing stream is further cooled against air in air cooler 208.
  • Water 212 is separated in drum 209. Part 210 of the synthesis gas containing stream is recycled to gasification reactor 201.
  • the remaining net synthesis gas containing stream or injection fluid 211 is preferably further dehydrated in a so-called TEG Dehydration Unit (not shown) before being compressed in compressor 213 to obtain a pressurized injection fluid 214 suited for injection in the hydrocarbon reservoir 219 as present below surface 218.
  • the subsurface reservoir 219 will produce a hydrocarbon stream 215 due to the resulting higher pressure in the reservoir 219.
  • a separation unit 216 may be part of the scheme. This unit 216 will separate the liquid condensates, the LPG fraction and optionally the ethane fraction (all shown as 217) from the produced gas 215.
  • the stream 202 may be gas 215 or a gas richer in methane 217 from which gas condensate, a LPG fraction and/or an ethane fraction is separated from. It will depend on the local value of these products whether they will be present in stream 202.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Hydrogen, Water And Hydrids (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

La présente invention concerne un procédé de production d’un flux d’hydrocarbure (110) à partir d’une zone souterraine (100) selon lequel un fluide d'injection (50) est injecté dans la zone souterraine (100), le procédé comprenant au moins les étapes consistant à : (a) fournir un fluide d'injection (50) comprenant un gaz de synthèse ; (b) injecter le fluide d'injection (50) dans une zone souterraine (100) pour obtenir une pression souhaitée dans celle-ci ; (c) obtenir un flux d’hydrocarbure (110) à partir de la zone souterraine (100).
PCT/EP2006/066473 2005-09-21 2006-09-19 Procédé de production d’un flux d'hydrocarbure à partir d'une zone souterraine WO2007039443A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
EP06793611A EP1926885A1 (fr) 2005-09-21 2006-09-19 Procédé de production d un flux d'hydrocarbure à partir d'une zone souterraine
CN200680034679.XA CN101268250B (zh) 2005-09-21 2006-09-19 从地下区域生产烃物流的方法
CA2620734A CA2620734C (fr) 2005-09-21 2006-09-19 Procede de production d'un flux d'hydrocarbure a partir d'une zone souterraine
JP2008530547A JP5468260B2 (ja) 2005-09-21 2006-09-19 地下帯域から炭化水素流を製造する方法

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
EP05108727 2005-09-21
EP05108727.8 2005-09-21

Publications (1)

Publication Number Publication Date
WO2007039443A1 true WO2007039443A1 (fr) 2007-04-12

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PCT/EP2006/066473 WO2007039443A1 (fr) 2005-09-21 2006-09-19 Procédé de production d’un flux d'hydrocarbure à partir d'une zone souterraine

Country Status (6)

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EP (1) EP1926885A1 (fr)
JP (1) JP5468260B2 (fr)
CN (1) CN101268250B (fr)
CA (1) CA2620734C (fr)
RU (1) RU2412340C2 (fr)
WO (1) WO2007039443A1 (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2008043833A2 (fr) * 2006-10-13 2008-04-17 Shell Internationale Research Maatschappij B.V. Procédé de préparation d'un mélange gazeux
EP2050809A1 (fr) * 2007-10-12 2009-04-22 Ineos Europe Limited Procédé pour obtenir des hydrocarbures d'un lit souterrain de schiste bitumineux ou de sable pétrolifère

Families Citing this family (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2018170830A1 (fr) * 2017-03-23 2018-09-27 陈信平 Procédé pour accroître la production de gaz de couche par injection d'air à haute température
RU2746005C2 (ru) * 2019-08-19 2021-04-05 Алексей Леонидович Западинский Комплекс для добычи углеводородов
RU2746004C2 (ru) * 2019-08-19 2021-04-05 Алексей Леонидович Западинский Способ добычи углеводородов

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US3150716A (en) * 1959-10-01 1964-09-29 Chemical Construction Corp Pressurizing oil fields
US4434852A (en) * 1981-08-31 1984-03-06 Texaco Inc. Method of enhanced oil recovery employing nitrogen injection
EP0342610A2 (fr) * 1988-05-18 1989-11-23 Air Products And Chemicals, Inc. Procédé de coproduction d'alcools supérieurs de méthanol et d'ammoniac
WO2003035591A1 (fr) * 2001-10-23 2003-05-01 Texaco Development Corporation Production de liquides et d'energie par procede fisher-tropsch
WO2004055323A1 (fr) * 2002-12-13 2004-07-01 Statoil Asa Installations et procede de recuperation accrue d'hydrocarbures

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ZA842807B (en) * 1983-05-31 1984-11-28 Westinghouse Electric Corp Gasification process for ammonia production
US6890962B1 (en) * 2003-11-25 2005-05-10 Chevron U.S.A. Inc. Gas-to-liquid CO2 reduction by use of H2 as a fuel

Patent Citations (5)

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Publication number Priority date Publication date Assignee Title
US3150716A (en) * 1959-10-01 1964-09-29 Chemical Construction Corp Pressurizing oil fields
US4434852A (en) * 1981-08-31 1984-03-06 Texaco Inc. Method of enhanced oil recovery employing nitrogen injection
EP0342610A2 (fr) * 1988-05-18 1989-11-23 Air Products And Chemicals, Inc. Procédé de coproduction d'alcools supérieurs de méthanol et d'ammoniac
WO2003035591A1 (fr) * 2001-10-23 2003-05-01 Texaco Development Corporation Production de liquides et d'energie par procede fisher-tropsch
WO2004055323A1 (fr) * 2002-12-13 2004-07-01 Statoil Asa Installations et procede de recuperation accrue d'hydrocarbures

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2008043833A2 (fr) * 2006-10-13 2008-04-17 Shell Internationale Research Maatschappij B.V. Procédé de préparation d'un mélange gazeux
WO2008043833A3 (fr) * 2006-10-13 2008-10-02 Shell Int Research Procédé de préparation d'un mélange gazeux
EP2050809A1 (fr) * 2007-10-12 2009-04-22 Ineos Europe Limited Procédé pour obtenir des hydrocarbures d'un lit souterrain de schiste bitumineux ou de sable pétrolifère

Also Published As

Publication number Publication date
CN101268250B (zh) 2013-05-29
EP1926885A1 (fr) 2008-06-04
CA2620734A1 (fr) 2007-04-12
JP2009508977A (ja) 2009-03-05
JP5468260B2 (ja) 2014-04-09
RU2412340C2 (ru) 2011-02-20
RU2008115427A (ru) 2009-10-27
CN101268250A (zh) 2008-09-17
CA2620734C (fr) 2014-04-22

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