US20130161011A1 - Method of using an oxygen stream as an oxidizer feed gas stream - Google Patents

Method of using an oxygen stream as an oxidizer feed gas stream Download PDF

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US20130161011A1
US20130161011A1 US13/537,946 US201213537946A US2013161011A1 US 20130161011 A1 US20130161011 A1 US 20130161011A1 US 201213537946 A US201213537946 A US 201213537946A US 2013161011 A1 US2013161011 A1 US 2013161011A1
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oxygen
nitrogen
carbon dioxide
hydrogen
air separation
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Ilaria CIATTAGLIA
Albrecht HEINZEL
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Linde GmbH
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Linde GmbH
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Priority claimed from US12/792,070 external-priority patent/US20110300054A1/en
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Assigned to LINDE AKTIENGESELLSCHAFT reassignment LINDE AKTIENGESELLSCHAFT ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: CIATTAGLIA, ILARIA, HEINZEL, ALBRECHT
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    • 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
    • C01B3/48—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 followed by reaction of water vapour with carbon monoxide
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • E21B43/164—Injecting CO2 or carbonated water
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    • 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
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    • 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
    • C01B3/38—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 catalysts
    • C01B3/382—Multi-step processes
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    • C01B3/50—Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification
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    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J3/00—Production of combustible gases containing carbon monoxide from solid carbonaceous fuels
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    • C10K—PURIFYING OR MODIFYING THE CHEMICAL COMPOSITION OF COMBUSTIBLE GASES CONTAINING CARBON MONOXIDE
    • C10K3/00—Modifying the chemical composition of combustible gases containing carbon monoxide to produce an improved fuel, e.g. one of different calorific value, which may be free from carbon monoxide
    • C10K3/02—Modifying the chemical composition of combustible gases containing carbon monoxide to produce an improved fuel, e.g. one of different calorific value, which may be free from carbon monoxide by catalytic treatment
    • C10K3/04—Modifying the chemical composition of combustible gases containing carbon monoxide to produce an improved fuel, e.g. one of different calorific value, which may be free from carbon monoxide by catalytic treatment reducing the carbon monoxide content, e.g. water-gas shift [WGS]
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    • C01B2203/0205—Processes for making hydrogen or synthesis gas containing a reforming step
    • C01B2203/0227—Processes for making hydrogen or synthesis gas containing a reforming step containing a catalytic reforming step
    • C01B2203/0244—Processes for making hydrogen or synthesis gas containing a reforming step containing a catalytic reforming step the reforming step being an autothermal reforming step, e.g. secondary reforming processes
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    • C01B2203/0283—Processes for making hydrogen or synthesis gas containing a CO-shift step, i.e. a water gas shift step
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    • C01B2203/04—Integrated processes for the production of hydrogen or synthesis gas containing a purification step for the hydrogen or the synthesis gas
    • C01B2203/0465—Composition of the impurity
    • C01B2203/0475—Composition of the impurity the impurity being carbon dioxide
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    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
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    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/80—Aspect of integrated processes for the production of hydrogen or synthesis gas not covered by groups C01B2203/02 - C01B2203/1695
    • C01B2203/84—Energy production
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/09—Details of the feed, e.g. feeding of spent catalyst, inert gas or halogens
    • C10J2300/0953—Gasifying agents
    • C10J2300/0959—Oxygen
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
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    • C10J2300/00—Details of gasification processes
    • C10J2300/16—Integration of gasification processes with another plant or parts within the plant
    • C10J2300/1603—Integration of gasification processes with another plant or parts within the plant with gas treatment
    • C10J2300/1612—CO2-separation and sequestration, i.e. long time storage
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
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    • C10J2300/00—Details of gasification processes
    • C10J2300/16—Integration of gasification processes with another plant or parts within the plant
    • C10J2300/164—Integration of gasification processes with another plant or parts within the plant with conversion of synthesis gas
    • C10J2300/1643—Conversion of synthesis gas to energy
    • C10J2300/1653—Conversion of synthesis gas to energy integrated in a gasification combined cycle [IGCC]
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
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    • C10J2300/00—Details of gasification processes
    • C10J2300/16—Integration of gasification processes with another plant or parts within the plant
    • C10J2300/1678—Integration of gasification processes with another plant or parts within the plant with air separation
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
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    • C10J2300/00—Details of gasification processes
    • C10J2300/18—Details of the gasification process, e.g. loops, autothermal operation
    • C10J2300/1846—Partial oxidation, i.e. injection of air or oxygen only
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • 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
    • Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
    • 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
    • Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
    • Y02E20/18—Integrated gasification combined cycle [IGCC], e.g. combined with carbon capture and storage [CCS]
    • 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
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P30/00—Technologies relating to oil refining and petrochemical industry

Abstract

A method for producing nitrogen for injection into an enhanced oil recovery operation wherein the nitrogen is produced in an air separation device and the oxygen stream produced is not discarded but recovered and employed with or without an additional air gas stream for feeding to a partial oxidation unit/autothermal reformer and shift conversion to produce carbon dioxide and hydrogen. The carbon dioxide can additionally be used for injection into an enhanced oil recovery operation and the hydrogen can be used as a fuel for a gas turbine driven closed cycle power plant for providing energy to the air separation device.

Description

    CROSS REFERENCE TO RELATED APPLICATIONS
  • This application claims priority from U.S. patent application Ser. No. 12/792,070 filed Jun. 2, 2010.
    • BACKGROUND OF THE INVENTION
  • The invention relates to a method for using the oxygen stream from an air separation unit producing nitrogen for injection into an enhanced oil recovery (FOR) operation as an oxidizer for an autothermal reforming/partial oxidation process to produce synthesis gas. The synthesis gas then undergoes a shift reaction whereby hydrogen and carbon dioxide are produced. The hydrogen can be employed to power the air separation unit and the carbon dioxide can be used for injection into an enhanced oil recovery operation. The presented method maximizes the amount of CO2 and N2 available for EOR.
  • Oil or gas and any water which is contained in the porous rock surrounding the oil or gas in a reservoir or formation are typically under pressure due to the weight of the material above them. As such, they will move to an area of lower pressure and higher elevation such as the well head. After some pressure has been released, the oil may still flow to the surface but it does so more slowly. This movement can be helped along by a mechanical pump such as the grasshopper pumps one often sees. These processes are typically referred to as primary oil recovery. Typically, less than 50% of the oil in the oil formation is recovered by primary techniques. Recovery can be increased by pursuing enhanced oil recovery (EOR) methods. Typically, these methods are divided into two groups: secondary and tertiary.
  • Secondary EOR generally refers to pumping a fluid, either liquid or gas, into the ground to build back pressure that was dissipated during primary recovery. The most common of these methods is to inject water and is simply called a waterflood.
  • The tertiary recovery schemes typically use chemical interactions or heat to either reduce the oil viscosity so the oil flows more freely or to change the properties of the interface between the oil and the surrounding rock pores so that the oil can flow out of the small pores in the rock and enter larger channels where the oil can be swept by a driving fluid or move by pressure gradient to a production well. The oil may also be swelled so that a portion of the oil emerges from small pores into the channels or larger pores in the rock. Typical of these processes are steam injection, miscible fluid injection and surfactant injection.
  • Thermal techniques employing steam can be utilized in a well to well scheme or also in a single-well technique which is know as the huff and puff method. In this method, steam is injected via a well in a quantity sufficient to heat the subterranean hydrocarbon-bearing formation in the vicinity of the well. The well is then shut in for a soaking period after which it is placed on production. After production has declined, the huff and puff method may again be employed on the same well to again stimulate production.
  • The use of carbon dioxide and its injection into oil reservoirs is known for well to well and single well production enhancement. The carbon dioxide dissolves in the oil easily and causes the oil to swell and reduces the viscosity and surface tension of the oil which in turn leads to additional oil recovery. The carbon dioxide may also be employed with steam such that the steam and carbon dioxide are injected either simultaneously or sequentially, often followed by a soak period, followed by a further injection of carbon dioxide or other fluids.
  • A facility that produces nitrogen for enhanced oil recovery can advantageously be modified to produce carbon dioxide for EOR. This modification needs to be accomplished with minimal modifications to the existing plant of an air separation unit powered by a natural gas fueled combined cycle power plant.
  • Traditionally carbon dioxide for EOR was captured in the gas turbine vent gas using an amine based solvent absorption system. The carbon dioxide can be recovered using a carbon dioxide-precombustion removal technology.
  • The inventors have discovered that the use of an enriched-oxygen feed stream in conjunction with a carbon rich fuel gas stream for synthesis gas production and downstream conversion would provide the carbon dioxide for EOR with minimal changes to the existing plant and decreased carbon dioxide emissions.
    • SUMMARY OF THE INVENTION
  • In a first embodiment, there is disclosed an improved method for producing nitrogen for injection into an enhanced oil recovery operation wherein the nitrogen is produced in an air separation device that also produces an oxygen-rich gas stream, the improvement comprising feeding the oxygen-rich gas stream to a partial oxidation unit/autothermal reformer and shift conversion to produce carbon dioxide and hydrogen.
  • In another embodiment there is disclosed an improved process for producing nitrogen for injection into an enhanced oil recovery operation wherein the nitrogen is produced in an air separation device that also produces an oxygen-rich gas stream, the improvement comprising feeding the oxygen-rich gas stream and air to a partial oxidation unit/autothermal reformer and shift conversion to produce carbon dioxide and hydrogen.
  • Typically when nitrogen is produced for injection into an enhanced oil recovery operation, it is produced from an air separation process. The air separation process will separate air into its constituent components namely nitrogen, oxygen and argon and the nitrogen will be stored and/or fed directly into the enhanced oil recovery operation. The oxygen separated from the nitrogen is typically discharged back into the atmosphere.
  • Rather than discharge this oxygen stream, the invention will produce nitrogen for injection into an enhanced oil recovery operation and rather than dispose of the oxygen stream separated from the nitrogen stream, will feed it to a partial oxidation/autothermal reformer as a feedstock in converting hydrocarbons into carbon dioxide and hydrogen. The improvement then is not disposing of the oxygen but recovering it and feeding it as a feedstock with or without air to a partial oxidation unit/autothermal reformer to produce chemical compounds that can be employed further in the enhanced oil recovery operation or in powering the air separation device.
  • In another embodiment of the invention there is disclosed a process for separating air to produce nitrogen for injection into an enhanced oil recovery operation and an oxygen gas stream comprising feeding the oxygen gas stream into a partial oxidation/autothermal reformer to produce carbon dioxide and hydrogen.
  • Accordingly the present invention will find applicability in an existing facility that produces nitrogen for injection into enhanced oil recovery operations by modifying the air separation process and recovering, storing and using the oxygen produced by the air separation process. The present invention also finds applicability in newly designed plants where the air separation process can accommodate the recovery of both nitrogen and oxygen gas streams.
  • A hydrogen rich gas is burnt in a combined cycle power plant that provides the power to drive the air separation units. The hydrogen rich fuel gas has to be diluted by nitrogen before it is fed to the burners of the gas turbine. The nitrogen dilution is required to secure a safe and environmental friendly operation. If one took the nitrogen that is produced for enhanced oil recovery (EOR) for diluting the hydrogen rich gas feedstock, then there is less nitrogen that is available for the enhanced oil recovery operation. As such, the invention takes the oxygen from the air separation unit (ASU) unit to feed the autothermal reformation/partial oxidation. This oxygen may be blended with some air (Option 2 as further detailed with regards to FIG. 2 below). Thus the nitrogen content of the hydrogen rich fuel gas can be adjusted to meet the maximum allowable hydrogen content of the gas turbine burners without consuming any of the nitrogen dedicated for EOR resulting in a more efficient use of the produced nitrogen. Alternatively some of the nitrogen that is dedicated for EOR can be used to dilute the hydrogen rich gas (Option 2). Option 2 however would reduce the amount of nitrogen available for EOR.
  • The enriched oxygen air gas stream is about 70 to 80% by volume oxygen and may be obtained as the “waste” gas stream from an air separation unit which is producing nitrogen for injection into the enhanced oil recovery process. The oxygen from the air separation unit in one embodiment can be supplemented with air to make the enriched oxygen gas stream. The use of the oxygen enriched stream from the air separation unit will have benefits in not only a reduction of plant size but also saves compressor power due to reduced processing of nitrogen needed.
  • The carbon rich fuel gas stream may be selected from any carbon containing stream that has a heating value greater than zero. In particular, the carbon rich fuel gas stream is a hydrocarbon or mixture of hydrocarbons selected from the group consisting of natural gas, oil, coal, refinery off gases and biomass.
  • The autothermal reformation/partial oxidation process is a single reactor which converts a fuel such as natural gas through a combination of partial oxidation and catalytic conversion to produce synthesis gas (hydrogen and carbon monoxide). In the partial oxidation section of the reactor, the natural gas is mixed with air and/or oxygen and steam in a burner or mixer where the partial combustion reaction takes place. This step is followed by a reformation reaction such as a steam methane reformation (SMR) reaction. The synthesis gas produced by this autothermal reformation/partial oxidation process is then followed by a shift conversion performed at high temperature and in the presence of a catalyst to form carbon dioxide and additional hydrogen.
  • The basic reactions are as such:

  • Partial Oxidation CH4+1/2O2→CO+2 H2

  • Steam Methane Reforming: CH4+H2O→CO+3 H2

  • Shift conversion: CO+H2O→CO2+H2
  • The combination of the non-catalytic partial oxidation and catalytic reformation results in an overall process that is relatively more energy efficient than using these two reaction units separately since the heat produced in the partial oxidation process can be transferred directly to the reformation reaction. Further, the size of the autothermal reformation/partial oxidation process unit can be minimized by use of the oxygen stream from the air separation process. Preferably, the autothermal reformation/partial oxidation process will provide synthesis gas having 65% maximum hydrogen content which is the target maximum for the combined cycle power plant.
  • The shift catalyst in the second reactor can be a low temperature shift catalyst or water gas shift reactor catalyst.
  • The shift reactor can be followed by a cooling step which will lower the temperature of the carbon dioxide and hydrogen prior to entry into the carbon dioxide removal unit.
  • In further embodiments of the invention, the hydrogen and carbon dioxide products of the shift reaction are fed to a carbon dioxide removal unit whereby carbon dioxide is recovered for injection into an enhanced oil recovery operation. The carbon dioxide separation is typically a MDEA physical wash process wherein 90% of the carbon dioxide can be recovered from the starting carbon rich fuel gas. However, other carbon dioxide separation means may be employed wherein both hydrogen and carbon dioxide are separated and recovered.
  • The hydrogen that is separated out is fed to a combined cycle power plant as fuel with the resulting waste flue gas being very low in carbon dioxides. The combined cycle power plant will provide power to the air separation unit producing the nitrogen for use in the EOR process. The combined cycle power plant is typically a gas turbine generator (GTG) and heat recovery steam generator (HRSG). The HRSG receives hot exhaust from a gas turbine to generate steam which in turn drives a steam turbine. This combination of GTG and HRSG will produce electricity which can be used to provide power to the air separation facility.
  • Some nitrogen may be recovered from the air separation unit product gas stream and it may be fed along with the hydrogen rich fuel gas from the carbon dioxide removal unit to dilute the fuel gas stream entering the combined cycle power plant. This is necessary as the content of the synthesis gas will have too much hydrogen (around 85%) which must be diluted down to about 65% for use in a gas turbine generator. This will enable the operator to avoid having to combine the enriched oxygen air gas stream with air.
    • BRIEF DESCRIPTION OF THE DRAWINGS
  • FIG. 1 is a schematic depiction of the invention where nitrogen from an air separation unit is fed to the hydrogen rich fuel gas line.
  • FIG. 2 is a schematic depiction of the invention where supplemental air feed is fed to the oxygen enriched air entering the autothermal reactor or partial oxidation reactor.
    •  DETAILED DESCRIPTION OF THE INVENTION
  • Turning to the drawings, FIG. 1 is a schematic of the invention whereby nitrogen is withdrawn from the product nitrogen from the air separation unit and combined with hydrogen rich fuel gas to dilute the fuel gas prior to entering the combined cycle power plant.
  • A carbon rich fuel is fed through line 1 to the autothermal reformation unit or partial oxidation unit A. The carbon rich fuel gas stream may be selected from any carbon containing stream that has a heating value greater than zero. In particular, the carbon rich fuel gas stream is a hydrocarbon or mixture of hydrocarbons selected from the group consisting of natural gas, oil, coal, refinery off gases and biomass. The gas stream 10 from the air separation unit E is primarily oxygen enriched air of about 70 to 80 volume percent oxygen which is fed to the autothermal reformation unit or partial oxidation unit A. Optionally, the oxygen enriched air can be fed through a booster compressor, not shown, prior to entering the autothermal reformation/partial oxidation unit. The autothermal reformation unit/partial oxidation unit will convert the oxygen and carbon rich feed into synthesis gas rich in hydrogen and carbon monoxide which is fed through line 2 to shift reactor B.
  • The partial oxidation or autothermal reforming unit is operated at a pressure of 10 to 100 bara. The partial oxidation process produces a raw gas at approximately 1300° to 1400° C. The raw gas is cooled down in a synthesis gas cooler or is quenched by water injection. The autothermal reforming process produces a raw synthesis gas at 900° to 1100° C. and is also cooled down in a synthesis gas cooler or quenching by water injection.
  • The shift reactor will produce a stream 3 of carbon dioxide and hydrogen which is fed to a carbon dioxide removal unit C where carbon dioxide which can be used in an enhanced oil recovery operation is withdrawn through line 4. The hydrogen rich fuel gas will exit the carbon dioxide removal unit C through line 5 where it will enter the combined cycle power plant D which contains a gas turbine (not shown). Part of the nitrogen produced by the air separation unit E is withdrawn from line 9 through line 8 where it will be combined with the hydrogen rich fuel gas in line 5 prior to entry into the combined cycle power plant D. The combined cycle power plant D will provide power through line 7 to the air separation unit E while producing a flue gas through line 6 that is very low in carbon dioxide content. The air separation unit E produces the nitrogen which is directed through line 9 for injection into an enhanced oil recovery operation. The hydrogen rich fuel gas can also be converted into electricity by using a fuel cell (not shown).
  • FIG. 2 uses the same designations for lines and operational units as FIG. 1 does. In the embodiment shown in FIG. 2, supplemental air is directed through line 11 to join with the oxygen enriched air in line 10 from the air separation unit E. This combined blended air/oxygen enriched air will enter the autothermal reformation unit or partial oxidation unit through line 10. Further in this embodiment, product nitrogen is not withdrawn from line 9 to be directed to the hydrogen rich fuel gas entering the combined cycle power plant D through line 5.
  • 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 (12)

Having thus described the invention, what we claim is:
1. An improved method for producing nitrogen for injection into an enhanced oil recovery operation wherein said nitrogen is produced in an air separation device that also produces an oxygen-rich gas stream, the improvement comprising feeding the oxygen-rich gas stream to a partial oxidation unit/autothermal reformer and shift conversion to produce carbon dioxide and hydrogen.
2. The method as claimed in claim 1 wherein said carbon dioxide is injected into an enhanced oil recovery operation.
3. The method as claimed in claim 1 wherein said air separation device is powered by a closed cycle power plant.
4. The method as claimed in claim 3 wherein said closed cycle power plant contains a gas turbine.
5. The method as claimed in claim 4 wherein hydrogen is used to fuel said gas turbine.
6. The method as claimed in claim 5 wherein nitrogen is blended with said hydrogen.
7. An improved process for producing nitrogen for injection into an enhanced oil recovery operation wherein said nitrogen is produced in an air separation device that also produces an oxygen-rich gas stream, the improvement comprising feeding the oxygen-rich gas stream and air to a partial oxidation unit/autothermal reformer and shift conversion to produce carbon dioxide and hydrogen.
8. The method as claimed in claim 7 wherein said carbon dioxide is injected into an enhanced oil recovery operation.
9. The method as claimed in claim 7 wherein said air separation device is powered by a closed cycle power plant.
10. The method as claimed in claim 9 wherein said closed cycle power plant contains a gas turbine.
11. The method as claimed in claim 10 wherein hydrogen is used to fuel said gas turbine.
12. The method as claimed in claim 7 wherein said oxygen-rich gas stream and said air are blended prior to being fed to said partial oxidation unit/autothermal reformer.
US13/537,946 2010-06-02 2012-06-29 Method of using an oxygen stream as an oxidizer feed gas stream Abandoned US20130161011A1 (en)

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US12/792,070 US20110300054A1 (en) 2010-06-02 2010-06-02 Method of using an oxygen waste stream as an oxidizer feed gas stream
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Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4434852A (en) * 1981-08-31 1984-03-06 Texaco Inc. Method of enhanced oil recovery employing nitrogen injection
US5458857A (en) * 1992-12-02 1995-10-17 Rolls-Royce, Plc Combined reformer and shift reactor
US20090293444A1 (en) * 2008-06-02 2009-12-03 Alstom Technologies, Ltd., Llc Gas turbine integrated with fuel catalytic partial oxidation

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4434852A (en) * 1981-08-31 1984-03-06 Texaco Inc. Method of enhanced oil recovery employing nitrogen injection
US5458857A (en) * 1992-12-02 1995-10-17 Rolls-Royce, Plc Combined reformer and shift reactor
US20090293444A1 (en) * 2008-06-02 2009-12-03 Alstom Technologies, Ltd., Llc Gas turbine integrated with fuel catalytic partial oxidation

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