Classifications

• • C—CHEMISTRY; METALLURGY
  • C01—INORGANIC CHEMISTRY
  • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
  • C01B3/00—Hydrogen; Gaseous mixtures containing hydrogen; Separation of hydrogen from mixtures containing it; Purification of hydrogen
  • C01B3/02—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen
  • C01B3/32—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air
  • C01B3/34—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents
  • C01B3/36—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents using oxygen or mixtures containing oxygen as gasifying agents
• • C—CHEMISTRY; METALLURGY
  • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
  • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
  • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
  • C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
  • C09K8/594—Compositions used in combination with injected gas, e.g. CO2 orcarbonated gas
• • 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
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
  • F23C—METHODS OR APPARATUS FOR COMBUSTION USING FLUID FUEL OR SOLID FUEL SUSPENDED IN  A CARRIER GAS OR AIR 
  • F23C10/00—Fluidised bed combustion apparatus
  • F23C10/005—Fluidised bed combustion apparatus comprising two or more beds
• • C—CHEMISTRY; METALLURGY
  • C01—INORGANIC CHEMISTRY
  • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
  • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
  • C01B2203/02—Processes for making hydrogen or synthesis gas
  • C01B2203/025—Processes for making hydrogen or synthesis gas containing a partial oxidation step
  • C01B2203/0255—Processes for making hydrogen or synthesis gas containing a partial oxidation step containing a non-catalytic partial oxidation step
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
  • F23C—METHODS OR APPARATUS FOR COMBUSTION USING FLUID FUEL OR SOLID FUEL SUSPENDED IN  A CARRIER GAS OR AIR 
  • F23C2900/00—Special features of, or arrangements for combustion apparatus using fluid fuels or solid fuels suspended in air; Combustion processes therefor
  • F23C2900/99008—Unmixed combustion, i.e. without direct mixing of oxygen gas and fuel, but using the oxygen from a metal oxide, e.g. FeO
• • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
  • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
  • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
  • Y02E20/00—Combustion technologies with mitigation potential
  • Y02E20/34—Indirect CO2mitigation, i.e. by acting on non CO2directly related matters of the process, e.g. pre-heating or heat recovery

Definitions

• This invention relates to a method for the recovery of hydrocarbons from a natural gas subsurface reservoir with nitrogen injection, whereby the nitrogen is prepared in a chemical looping combustion reactor. It also relates to the method wherein a combination of nitrogen with CO 2 is used for injection in the reservoir. The invention also relates to an integrated production system with nitrogen injection and a chemical combustion unit.
• EGR Enhanced Gas Recovery
• EGR Enhanced Gas Recovery
• Nitrogen containing less than 10 ppm oxygen and/or CO 2 containing less than 10 ppm oxygen, as well as flue gases (mixtures of CO 2 , N 2 , Ar and other trace compounds present in air) containing less than 10 ppm oxygen can be used as injection gas, to purge the reservoirs .
• Nitrogen gas is commonly used in industry. It is typically produced by the fractional distillation of liquid air, or by mechanical means using gaseous air (i.e., pressurized reverse osmosis membrane or Pressure swing adsorption) . Commercial nitrogen is often a
• OFN oxygen-free nitrogen
• Pressure maintenance can significantly increase the amount of economically recoverable oil over that to be expected with no pressure maintenance.
• Nitrogen has long been successfully used as injection fluid for EOR and is widely used in oil field operations for gas cycling, reservoir pressure maintenance, and gas lift.
• the costs and limitations on the availability of natural gas and CO2 have in some cases made nitrogen an economic alternative for oil recovery by miscible gas displacement.
• WO2011084581 US2011146978
• an enhanced oil recovery process is known that is integrated with a synthesis gas generation process, such as gasification or reforming, and an air separation process for generating (i) an oxygen stream for use, for example, in the syngas process or a combustion process, and (ii) a nitrogen stream for EOR use. It is indicated that air separation units suitable for use in this process are well-known to those of ordinary skill in the relevant art.
• Examples of well-known air separation technologies include, for example, cryogenic distillation, ambient temperature adsorption and membrane separations.
• the integration according to WO2011084581 is to utilize a conventional air separation unit and use both the oxygen stream and the nitrogen stream on-site. The economic benefit is therefore marginal. Moreover, there is no guarantee that the nitrogen stream is indeed oxygen-free.
• a method for recovering hydrocarbons from a reservoir which includes separating air into a nitrogen-rich gas and an oxygen-rich gas, oxidizing a hydrocarbon fuel with at least part of the oxygen-rich gas to produce steam and a C02-rich gas, injecting at least part of the steam through an injection well into the reservoir to heat the hydrocarbons, purging the injection well with at least part of the nitrogen- rich gas, and injecting at least part of the C02-rich gas into the reservoir containing the heated hydrocarbons.
• this reference use is made both of the nitrogen
• WO03016676 relates to an energy-integrated process scheme for the production of liquid hydrocarbons from light hydrocarbons.
• an EOR process is combined with the production of liquid hydrocarbons.
• a mixture of oxygen and nitrogen e.g. air
• the nitrogen stream obtained is used for EOR, and the oxygen stream obtained is used for partial oxidation of a
• hydrocarbonaceaous feed e.g. associated gas
• syngas hydrocarbonaceaous feed
• WO03018958 relates to a process in which a nitrogen stream from an air separation unit is used for EOR, and the oxygen stream is used for the production of syngas.
• Fuel reactor flue gases 90 may pass a heat recovery steam generator 190 to heat boiler feed water 200 to provide steam 210.
• air reactor flue gases 110 may pass through a heat recovery steam
• the generator 260 to heat boiler feed water 200 to provide steam 210.
• the steam 210 may be used in enhanced oil recovery, for example in SAGD.
• WO2011084581, W02008087154 , WO03016676 and WO03018958 thus all relate to processes in which a nitrogen-rich gas from an air separation unit (ASU) is used for artificial maintenance of formation pressure during EOR.
• ASU air separation unit
• US2012214106 discloses a process in which steam is used in EOR, e.g. in SAGD, whereby the steam is generated in a heat recovery steam generator in a CLC line-up.
• the current invention especially relates to the specific feature of EGR that it concerns a gas-gas displacement process for nearly depleted natural gas subsurface reservoirs, and that at some point in time the gas that is injected will reach the production well, thus diluting the produced natural gas stream.
• the problem underlying the current invention is to find a means for maximum hydrocarbon recovery from a natural gas subsurface reservoir.
• the present invention provides a process for the recovery of hydrocarbons from a natural gas subsurface reservoir
• the nitrogen stream (i) is prepared in and captured from a chemical looping combustion reactor wherein a fuel is combusted through use of an oxygen carrier with a gas stream (ii) containing both oxygen and nitrogen, and
• the present invention further provides an integrated production system with nitrogen injection for recovering hydrocarbons from a natural gas subsurface reservoir, comprising :
• the compression unit is connected with at least one injection well
• Subsurface fossil-fuel wells come in many varieties. There can be wells that produce oil, wells that produce oil and natural gas, or wells that only produce natural gas.
• the current invention can be applied in respect of gas wells.
• the invention can be applied on land but also offshore. The invention can be applied, typically, when the production of the subsurface reservoir diminishes.
• the current method relates to a method for recovering hydrocarbons from a natural gas subsurface reservoir.
• the present invention provides a process for the recovery of hydrocarbons from a natural gas subsurface reservoir
• the nitrogen stream (i) is prepared in and captured from a chemical looping combustion reactor wherein a fuel is combusted through use of an oxygen carrier with a gas stream (ii) containing both oxygen and nitrogen, and
• the fuel that is combusted in the chemical looping combustion reactor may have a Wobbe index in the range of 3 to 40 MJ/Nm 3 , even of 5 to 27 MJ/Nm 3 .
• the fuel that is combusted in the chemical looping combustion reactor preferably contains up to 95% by volume of nitrogen and/or carbon-dioxide.
• the oxygen to fuel molar ratio in the chemical looping combustion reactor preferably is in the range of 0.8 - 1.2.
• the metal of the oxygen carrier preferably is
• Ni, Mn, Cu, Cd, Co, Fe, Mg or Ca selected from Ni, Mn, Cu, Cd, Co, Fe, Mg or Ca, and wherein the metal is preferably deposited on a solid carrier .
• the nitrogen stream (i) captured from the chemical looping combustion reactor preferably is routed to a polishing step to reduce the oxygen content to less than
• the gas stream (ii) containing both oxygen and nitrogen preferably contains more than 75 % by volume, preferably more than 85 % by volume, more preferably more than 90 % by volume of nitrogen.
• the gas stream (ii) containing both oxygen and nitrogen preferably is enriched in nitrogen content by a membrane unit.
• a flue gas stream is produced in the chemical looping combustion reactor and at least a part thereof is used in combination with the nitrogen stream (i) as injection gas for the natural gas reservoir. More preferably steam and/or power is produced during chemical looping combustion and at least a part thereof is used to compress the nitrogen stream (i) prior to injection, or to compress the gas stream (ii) containing both oxygen and nitrogen prior to the chemical looping combustion reactor .
• the present invention further provides an integrated production system with nitrogen injection for recovering hydrocarbons from a natural gas subsurface reservoir, comprising :
• the compression unit is connected with at least one injection well
• a nitrogen stream (i) is prepared in and captured from a chemical looping combustion reactor (CLC reactor) wherein a fuel is combusted through use of an oxygen carrier with a gas stream (ii) containing both oxygen and nitrogen.
• CLC reactor chemical looping combustion reactor
• the method may, for example, include separating a nitrogen stream (i) from air, by oxidizing a fuel with the oxygen in the air in a chemical looping combustion reactor .
• the combustion in the CLC reactor produces two separate streams: a nitrogen stream and a flue gas stream.
• the nitrogen gas mainly comprises nitrogen and preferably comprises, optionally after a polishing step, less than 10 ppm oxygen.
• the flue gas stream may comprise carbon-dioxide, steam, unburned hydrocarbons and/or reforming products such as carbon-monoxide and hydrogen.
• the fuel may be fully oxidized or partially oxidized.
• a chemical looping combustion reactor also referred to as chemical looping combustion unit, comprises an air reactor (AR) and a fuel reactor (FR) .
• the reaction in the fuel reactor can be slightly exothermic or endothermic, depending on the nature of the oxygen carrier.
• the main heat is produced in the exothermic reaction in the air reactor and can be used for the production of hot steam and for electric power.
• the CLC unit also referred to as CLC reactor, used in the present invention acts as a highly selective separator. It may be used to remove oxygen out of air, thereby producing a substantially oxygen-free nitrogen stream (i) , i.e. with less than 10 ppm oxygen. Moreover, this avoids contamination of the nitrogen stream (i) with flue gas components, such as CO 2 and 3 ⁇ 40.
• CLC units Chemical looping combustion (CLC) units are known.
• CLC units comprise an air reactor (AR) and a fuel reactor (FR) .
• oxygen carrier a metal or metal oxide in a reduced state.
• oxygen carrier a metal or metal oxide in a reduced state.
• the oxygen in the stream containing both oxygen and nitrogen e.g., air, but also streams containing less oxygen - e.g. a secondary flue gas from a combustion unit other than a CLC unit
• Near complete removal of the oxygen may be reached in one pass through one AR.
• the air stream may be passed more than once through the AR until the oxygen therein is largely removed, or the air stream may be passed through more than one AR until the oxygen therein is largely removed.
• the air reactor exhaust stream which is a nitrogen stream, can be routed to a polishing step that reduces the oxygen content to the required levels.
• the oxygen content of the AR exhaust stream i.e. the nitrogen stream, is reduced to less than 10 ppm by volume without the need of a polishing step.
• An advantage of the current method and production system is that maximum hydrocarbon recovery from a natural gas subsurface reservoir can be obtained. Before and during the time that the gas that is injected in the natural gas subsurface reservoir starts to dilute the produced natural gas stream, the current invention is advantageous. Especially when the produced natural gas stream becomes diluted the present invention results in a higher hydrocarbon recovery as compared to known methods and production systems.
• Wobbe index can be fed to the fuel reactor of the CLC unit.
• EGR starts to produce one or more natural gas production streams with more than 20% nitrogen
• this/these stream(s) is/are used as fuel for the CLC, and is/are further turned into valuable nitrogen stream(s) .
• Another advantage is that the current method and production system are less complicated than known methods and production systems. They require a minimum amount of apparatuses and are economically attractive.
• the CLC is fully integrated, using the exhaust stream of the air reactor of the CLC for nitrogen injection in a natural gas subsurface reservoir, running the fuel reactor of the CLC on a hydrocarbon stream recovered from the natural gas subsurface reservoir, and using the power generated by the CLC unit for compression. EGR can even be continued when the
• hydrocarbon stream recovered from the natural gas subsurface reservoir is a low value fuel having a low Wobbe index. This results in maximum hydrocarbon recovery from the natural gas subsurface reservoir.
• the CLC unit produces power (steam) .
• this may be used to efficiently compress air to the CLC operational pressure and/or compress the produced nitrogen containing stream to a pressure suitable for injection.
• the CO2 rich flue gas stream produced as exhaust of the FR in the CLC unit may also be used as additional injection gas in a later phase of the EGR development, e.g. after 20% of the volume of the
• subsurface reservoir has been purged with the nitrogen containing stream that was initially injected.
• a gas stream comprising N 2 , CO2 and O2 at a reduced O2 concentration, meaning less than 20 %v, but more than 10 ppm.
• this may be a flue gas stream of e.g. a separate combustion unit, instead of air. This will lead to a higher amount of 2 produced per amount of fuel combusted.
• resulting air reactor exhaust will contain a mixture mainly of 2 and CO2.
• This nitrogen containing stream can be used directly or if required via an oxygen polishing step (discussed hereafter) for EGR.
• (A) represents the fuel. This may be fuel with a low
• Wobbe index for example gas recovered from a nearly depleted reservoir;
• (B) represents air or similar stream containing both oxygen and nitrogen. This stream may be compressed;
• (C) represents air depleted in 0 2 ;
• (D) represents steam (and power) ;
• (E) represents flue gas.
• (1) represents a fuel reactor (FR)
• (3) represents a loop wherein oxygen loaded carriers and depleted oxygen carriers are re-circulated from (AR) to (FR) and from (FR) to (AR) respectively.
• FIGS 2 to 6 various line-ups are shown. All embodiments concern Enhanced Gas Recovery (EGR) .
• Figures 4 and 5 are according to the present invention.
• Figures 2, 3 and 6 show line-up configurations that may be part of a line-up according to the present invention.
• EGR Enhanced Gas Recovery
• Hot flue gas (mainly CO2 and 3 ⁇ 40)
• A represents an optional compression unit
• C represents a steam boiler
• D represents a split, wherein CO 2 stream is split for
• E represents a compression unit operating at greater than reservoir pressure conditions
• F represents an N number of injection well heads
• G represents subsurface reservoir (s)
• H represents a produced natural gas gathering system
• I represents a produced natural gas conditioning
• J represents a nitrogen enrichment unit (that
• FIG. 2 Enhanced Gas Recovery with compressed nitrogen which comprises less than 10 ppm oxygen.
• air may be first compressed in unit A before it is introduced into the CLC unit B.
• the CLC unit may be run at atmospheric conditions.
• the product streams of the CLC unit are hot and the energy may be recovered in for instance the steam boiler C.
• Nitrogen with less than 10 ppm nitrogen may then be compressed in unit E and injected via injection well heads F into the subsurface reservoir. This may be a singular reservoir or a number of reservoirs.
• Figure 3 is a modification, wherein (part) of the CO 2 stream is compressed and also introduced in the
• this is done after about 20% of the volume of the reservoir (s) has been purged with the nitrogen containing stream.
• Figures 4 and 5 are modifications of Figures 2 and 3, wherein is shown that part of the recovered gas stream is used as fuel gas feed.
• Part of the hydrocarbons recovered from a natural gas subsurface reservoir are used as fuel in the chemical looping combustion reactor.
• the fuel in the chemical looping combustion reactor may contain up to 95% by volume of 2 and/or CO 2 .
• Such commercially low value fuel has a Wobbe index in the range of 3 to 40 MJ/Nm 3 , preferably 5 to 27 MJ/Nm 3 .
• FIG. 6 a line-up is shown wherein a unit is used that results in an oxygen enriched stream and an oxygen reduced stream.
• CLC conditions are known.
• a chemical- looping combustor is used, composed of two interconnected fluidized bed reactors, a fuel reactor (FR) and an air reactor (AR) , separated by a loop seal.
• the chemical- looping reactors (AR and FR) can be designed as risers or bubbling fluidized beds.
• the reactor designs are preferably optimized with respect to the nature of the oxygen carrier (e.g., density, and kinetics).
• reactors may further comprise a cyclone and a solid valve to control the solids fed to the fuel reactor (FR) , or similar equipment.
• the fuel combustion is performed by an oxygen carrier, giving CO 2 and 3 ⁇ 40.
• the solids in this respect are particles of the oxygen carrier. Depleted oxygen carrier particles overflow into the AR through another loop seal, preferably through a U- shaped fluidized loop seal, to avoid gas mixing between fuel and air.
• the loop seals are preferably fluidized by steam.
• the loading of the oxygen carrier takes place at the AR, which can be designed as a riser or a bubbling fluidized bed depending on the nature of the oxygen carrier. In the present set-up, it is important to select conditions that also ensure complete absorption of the oxygen. 2 leaves the AR, for instance, passing through a high-efficiency cyclone and a filter or similar
• the 2 is routed to a polishing step, to remove any remaining traces of 0 2 .
• the recovered solid particles enter the upper loop seal that is
• the recovered solid particles may be partly sent to a reservoir of solids where heat is recovered in a bubbling fluidized bed heat exchanger.
• the oxygen carrier particles may be returned to the AR by gravity from the reservoir of solids located above a solids valve. Fine particles produced by
• fragmentation/attrition in the plant are preferably recovered, for instance in filters that are located downstream of the FR and AR.
• Various oxygen carriers in CLC processes are known and suitable.
• the oxygen carrier particles are a cornerstone in the CLC technique. Important properties for oxygen carriers are high
• Suitable metals include Ni, Mn, Cu, Cd, Co, Fe, Mg and Ca.
• the oxygen carrier (OC) in the current process is preferably a Cu-based oxygen carrier, an Fe-based oxygen carrier or an Ni-based oxygen carrier, more preferably a Cu-based oxygen carrier, with the metal deposited on a solid support.
• these metal oxides are combined with an inert which acts as a porous support providing a higher surface area for reaction, as a binder for
• AI2O3, S1O2, T1O2, and Zr02 are usually used as the inert support. They have the ability to increase the
• the inert materials are believed to enhance positive properties among which the most
• silica or alumina supports are used, more preferably Y-AI 2 O 3 .
• Suitable oxygen carriers may for instance be found in "Selection of Oxygen Carriers for Chemical-Looping Combustion", by J. Adanez et al in
• oxygen carriers are also suitable as oxygen carriers.
• the reaction conditions in the AR are such as to convert the OC without adversely affecting the OC itself and without the generation of NO x .
• the operational pressure of the CLC can be chosen freely, and follows from a cost optimization where the main parameters are reactor volume for a given capacity (which reduces with increasing reactor pressure) and air compression (which increases with increasing reactor pressure) .
• the pressure can be in the range from 1 to 10 bara, more preferably from 1 to 5 bara.
• the conditions should be selected such as to ensure complete adsorption of the oxygen.
• the residence time should be selected appropriately as well as the temperature and the oxygen carrier to fuel ratio.
• the FR might be
• the temperature may vary from
• the gas stream (ii) containing both oxygen and nitrogen preferably contains less than 25 % by volume of oxygen, with the remainder being nitrogen or nitrogen and other inert gasses. More preferably it contains less than 15 % by volume of oxygen, more
• the gas stream (ii) containing both oxygen and nitrogen contains more than 75 % by volume, preferably more than 85 % by volume, more preferably more than 90 % by volume of nitrogen .
• reaction conditions in the FR are such as to convert at least 90 vol%, preferably at least 95 vol% of the fuel with the oxidized OC without adversely affecting the OC itself. Partial combustion may be used for
• the fuel is preferably combusted fully, without the generation of partially combusted products.
• the pressure and temperature in the FR and the AR are substantially the same (that is, they differ less than 1 bara, preferably less than 200 mbar in pressure) .
• the pressure can be in the range from 1 to 80 bara, more preferably from 1 to 10 bara.
• the temperature may vary from 700 to 1200°C, preferably from 850 to 950°C.
• the air to fuel molar ratio is in the range of 0.4 - 10, more preferably in the range of 0.6 - 3.0, most preferably in the range of 0.8 - 1.2.
• Oxygen carrier to fuel ratios that are suitable for full combustions are known in the art and may be easily determined when carrying out a series of experiments. On the other hand, the ratio should be close to the ideal amount for full combustion of the fuel, however slightly reducing conditions in the FR might be required for full O 2 removal in the AR. Suitable ratios to be used range from 0.2 - 10 (mol OC/mol fuel), more preferably from 0.4
• the waste stream from the AR is composed of 2 that is essentially free of O 2 , and trace amounts of other components present in air. It may be converted into pure 2 with an optional subsequent oxygen polishing step. For instance, the nitrogen may be treated in a catalyst bed to remove the detectable traces of oxygen.
• the current invention concerns a method for Enhanced Gas Recovery. It is within the scope of the invention to have the CLC unit and other units at some distance of the well heads.

Landscapes

• Chemical & Material Sciences (AREA)
• Engineering & Computer Science (AREA)
• Life Sciences & Earth Sciences (AREA)
• Organic Chemistry (AREA)
• Geology (AREA)
• Chemical Kinetics & Catalysis (AREA)
• General Life Sciences & Earth Sciences (AREA)
• Combustion & Propulsion (AREA)
• Mining & Mineral Resources (AREA)
• Materials Engineering (AREA)
• Fluid Mechanics (AREA)
• Environmental & Geological Engineering (AREA)
• Geochemistry & Mineralogy (AREA)
• Physics & Mathematics (AREA)
• Mechanical Engineering (AREA)
• General Engineering & Computer Science (AREA)
• Oil, Petroleum & Natural Gas (AREA)
• Health & Medical Sciences (AREA)
• General Health & Medical Sciences (AREA)
• Inorganic Chemistry (AREA)
• Hydrogen, Water And Hydrids (AREA)

Priority Applications (1)

Applications Claiming Priority (3)

Publications (1)

Family

ID=47355886

Family Applications (1)

Country Status (2)

Families Citing this family (5)

Citations (1)

Family Cites Families (6)

• 2013
  • 2013-12-13 EP EP13803080.4A patent/EP2931830A1/de not_active Withdrawn
  • 2013-12-13 WO PCT/EP2013/076626 patent/WO2014091024A1/en active Application Filing

Patent Citations (1)

Non-Patent Citations (1)

Also Published As

Similar Documents

Legal Events