US20120227964A1 - Carbon dioxide gas mixture processing with steam assisted oil recovery - Google Patents

Carbon dioxide gas mixture processing with steam assisted oil recovery Download PDF

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Publication number
US20120227964A1
US20120227964A1 US13/042,096 US201113042096A US2012227964A1 US 20120227964 A1 US20120227964 A1 US 20120227964A1 US 201113042096 A US201113042096 A US 201113042096A US 2012227964 A1 US2012227964 A1 US 2012227964A1
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US
United States
Prior art keywords
flue gas
carbon dioxide
steam
oxygen
oil
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
Application number
US13/042,096
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English (en)
Inventor
David C. LaMont
James P. Seaba
Thomas J. Wheeler
Edward G. Latimer
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ConocoPhillips Co
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ConocoPhillips Co
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 ConocoPhillips Co filed Critical ConocoPhillips Co
Priority to US13/042,096 priority Critical patent/US20120227964A1/en
Priority to CA2827765A priority patent/CA2827765A1/fr
Priority to PCT/US2011/027574 priority patent/WO2012121710A1/fr
Assigned to CONOCOPHILLIPS COMPANY reassignment CONOCOPHILLIPS COMPANY ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: SEABA, JAMES P., LATIMER, EDWARD G., LAMONT, DAVID C., WHEELER, THOMAS J.
Publication of US20120227964A1 publication Critical patent/US20120227964A1/en
Abandoned legal-status Critical Current

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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
    • E21B43/2406—Steam assisted gravity drainage [SAGD]
    • E21B43/2408—SAGD in combination with other methods

Definitions

  • Embodiments of the invention relate to methods and systems for processing carbon dioxide in flue gas from oxy-fuel combustion utilizing steam assisted oil recovery.
  • Oxy-fuel combustion refers to burning of fuel in oxygen (e.g., 95% pure oxygen) instead of air to reduce amount of nitrogen in resulting flue gas.
  • the flue gas from the oxy-fuel combustion thus contains carbon dioxide and water vapor, which can be removed if condensed through cooling.
  • the oxy-fuel combustion facilitates carbon dioxide capture since the flue gas is almost pure carbon dioxide with trace amounts of impurities, such as oxygen (e.g., about 0.1-2 volume percent) remaining due to equilibrium constraints as well as local mixing conditions during combustion.
  • the oxygen in the carbon dioxide makes transportation of the carbon dioxide to a sequestration site problematic since the oxygen causes corrosion.
  • Common carbon dioxide quality specifications for pipeline transport require oxygen content to be below 0.001 by volume.
  • Cryogenic distillation provides one option for removing the oxygen but requires additional expense and results in loss of 7-10 percent of the carbon dioxide.
  • Alternate approaches utilize the flue gas from the oxy-fuel combustion. For example, injecting the flue gas into reservoirs of natural gas helps displace the natural gas. However, gas phase interactions of the flue gas in the reservoirs and the interactions not occurring at where the reservoir is being heated limits any possible oxygen removal from the carbon dioxide.
  • a method in one embodiment, includes forming a mixture of flue gas from oxy-fuel combustion and steam generated prior to being mixed with the flue gas.
  • the flue gas contains carbon dioxide with an initial concentration of oxygen that is at least 0.1 volume percent.
  • injecting the mixture into a subterranean formation heats oil in the formation and reacts with the oil at least some of the oxygen that is from the flue gas and is dissolved in liquid condensate of the steam.
  • the method further includes recovering fluids including the oil that is heated and carbon dioxide from the flue gas and separating the fluids recovered to isolate from a liquid phase the carbon dioxide containing less than the initial concentration of oxygen for transporting the carbon dioxide to a sequestration site.
  • a method includes producing flue gas from oxy-fuel combustion, generating steam without contact of the steam with the flue gas, and introducing the steam into the flue gas to form a mixture.
  • the flue gas contains carbon dioxide with quantities of oxygen greater than a transport specification.
  • the method includes injecting the mixture into a subterranean formation for heating oil in the formation, recovering fluids including the oil that is heated and the carbon dioxide from the flue gas, and separating the fluids into liquids and vapors.
  • the vapors formed of the carbon dioxide meet the transport specification due to removal of at least some of the oxygen by oxidation of the oil upon the oxygen being dissolved in condensate of the steam for liquid phase reactions at temperatures elevated by the steam.
  • the method further includes transporting to a sequestration site the carbon dioxide obtained by the separating.
  • a system includes a supply of flue gas from an oxy-fuel combustion chamber, a source of steam generated without contact of the steam with the flue gas, and an injection well disposed in a subterranean formation containing oil.
  • the injection well couples in fluid communication with the supply of the flue gas and the source of the steam.
  • a vapor-liquid separator of the system receives produced fluids heated by the steam.
  • the vapor-liquid separator also outputs carbon dioxide that is in the produced fluids from the flue gas and is processed by liquid phase reactions between the oil heated by the steam and at least some oxygen that is from the flue gas and is dissolved in condensate of the steam.
  • FIG. 1 is a schematic of a production system for both purification of carbon dioxide in flue gas and steam assisted oil recovery, according to one embodiment of the invention.
  • Embodiments of the invention relate to methods and systems for processing flue gas from oxy-fuel combustion.
  • Steam generated without contact of the steam with the flue gas combines with the flue gas for injection into a formation to facilitate oil recovery from the formation.
  • Fluids produced include the oil and carbon dioxide with a lower concentration of oxygen than present in the flue gas that is injected.
  • FIG. 1 illustrates a system with an injection well 101 and a production well 102 that traverse through an earth formation 103 containing petroleum products, such as heavy oil or bitumen.
  • the system further includes a steam generator 104 to supply a flow of steam 105 to the injection well 101 .
  • the steam generator 104 and/or a separate heating unit 106 produce flue gas 107 from oxy-fuel combustion.
  • the oxy-fuel combustion produces the flue gas 107 containing carbon dioxide with at least 0.1 volume percent oxygen as a result of burning fuel in oxygen, such as at least about 95% by volume pure oxygen separated from air.
  • the carbon dioxide may make up by volume at least about 85%, at least about 90%, or at least about 95% of the flue gas 107 .
  • Sources for the fuel include coal, petroleum coke, asphaltenes, methane, natural gas and hydrogen. To limit resulting flame temperatures to levels common during conventional combustion and within thermal thresholds, some cooled combustion gases may circulate back and be injected into a combustion chamber used for the oxy-fuel combustion.
  • a burner heats a boiler within the steam generator 104 for making the steam 105 without initial contact of the flue gas 107 with the steam 105 in the steam generator 104 since an inside of the boiler is sealed from the burner, which may define the chamber for the oxy-fuel combustion.
  • the flue gas 107 combines with the steam 105 to form a mixture after the steam 105 is generated.
  • the mixture passes into the injection well 101 upon introducing the flue gas 107 into the steam 105 between the steam generator 104 and the injection well 101 .
  • the mixture may in some embodiments further contain a solvent for the products added to help mobilize the products, which are more viscous than the solvent. Examples of the solvent introduced into the mixture include hydrocarbons, such as at least one of propane, butane, pentane, hexane, heptane, naphtha, natural gas liquids and natural gas condensate.
  • the mixture makes the petroleum products mobile enough to enable or facilitate recovery with, for example, the production well 102 .
  • the injection well 101 includes a horizontal borehole portion that is disposed above (e.g., 0 to 6 meters above) and parallel to a horizontal borehole portion of the production well 102 . While shown in an exemplary steam assisted gravity drainage (SAGD) well pair orientation, some embodiments utilize other configurations of the injection well 101 and the production well 102 , which may be combined with the injection well 101 or arranged crosswise relative to the injection well 101 , for example.
  • SAGD steam assisted gravity drainage
  • a vapor chamber develops in the formation 103 and grows as the products are recovered. Walls of the vapor chamber form an interface with the products where the steam 105 condenses transferring heat to the products that then drain to the production well 102 . Since the flue gas 107 containing the oxygen is injected into the vapor chamber during development of the chamber, the oxygen contacts this condensate of the steam 105 and is dissolved in the condensate enabling both the condensate to carry oxygen into the products and liquid phase reaction of the oxygen with the products. For some embodiments, effective removal of the oxygen from the carbon dioxide in the flue gas 107 relies on the reactions being in liquid phase compared to inefficient gas contact of the oxygen with the products.
  • this oxidation of the products further depends on temperature at which the oxygen contacts the products since oxygen uptake by the products increases with rising temperature.
  • the reactions for some embodiments occur at temperatures that are elevated by the steam 105 and may be above about 100° C., above about 150° C. or above about 200° C.
  • Injection of the flue gas 107 through a separate well and outside of the vapor chamber formed by the steam 105 heating the products tends to keep the oxygen in gas phase and insulated from thermal heating by the steam 105 due to physical separation of the oxygen from the condensate.
  • injection of the flue gas 107 after stopping injection of the steam 105 prevents ability of the oxygen to be dissolved in the condensate and carried into the products at as high a temperature as possible. While helpful for processing the carbon dioxide in the flue gas 107 , the oxidation of the products lacks influence on recovery due to only trace amounts of the oxygen in the flue gas 107 .
  • the carbon dioxide from the flue gas 107 also dissolves into the products reducing viscosity of the products to facility production.
  • the formation 103 retains some amount of the carbon dioxide from the flue gas 107 .
  • Pore space opened from one barrel of produced oil stores about 8 kilograms of the carbon dioxide.
  • the carbon dioxide being held in the formation 103 remains sequestered without requiring any additional treatment to be captured.
  • Fluid recovered from the production well 102 enters into a separator 110 for separation of a liquid phase 111 from a vapor phase 112 .
  • the liquid phase 111 includes the petroleum products and water, which may be separated from the products and recycled along with any solvent removed from the products.
  • the carbon dioxide from the flue gas 107 forms the vapor phase 112 and may make up by volume at least about 90%, or at least about 95% of the vapor phase 112 .
  • Lack of substantial quantities of nitrogen in the flue gas 107 due to the oxy-fuel combustion limits nitrogen amounts in the vapor phase 112 ensuring that the carbon dioxide therein remains concentrated for desired capture and sequestration.
  • the vapor phase 112 contains a lower concentration of the oxygen than is present in the flue gas 107 prior to introduction into the injection well 101 .
  • the flue gas 107 with the at least 0.1 volume percent oxygen before being introduced into the injection well 101 prevents the flue gas 107 from meeting transport specifications. For example, oxygen content of above 0.001% by volume in the flue gas 107 as produced from the oxy-fuel combustion may reduce to below 0.001% by volume in the vapor phase 112 and thereby be below the transport specifications.
  • transport of the carbon dioxide includes compressing the vapor phase 112 that is then passed through a pipeline.
  • the pipeline may carry the carbon dioxide to a sequestration facility such as a geologic reservoir distant from the formation 103 in which the products are recovered.
  • injection of the flue gas 107 from the oxy-fuel combustion into a depleted hydrocarbon reservoir passes the flue gas 107 into contact with unrecovered petroleum products that react with the oxygen from the flue gas 107 .
  • Such oxidation scrubs oxygen from the flue gas 107 leaving the carbon dioxide that may be subsequently recovered for transporting even though no hydrocarbons are also produced while recovering the carbon dioxide.
  • some embodiments may inject the flue gas 107 without mixing the flue gas 107 with the steam 105 .

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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)
  • Treating Waste Gases (AREA)
  • Carbon And Carbon Compounds (AREA)
  • Gas Separation By Absorption (AREA)
US13/042,096 2011-03-07 2011-03-07 Carbon dioxide gas mixture processing with steam assisted oil recovery Abandoned US20120227964A1 (en)

Priority Applications (3)

Application Number Priority Date Filing Date Title
US13/042,096 US20120227964A1 (en) 2011-03-07 2011-03-07 Carbon dioxide gas mixture processing with steam assisted oil recovery
CA2827765A CA2827765A1 (fr) 2011-03-07 2011-03-08 Traitement d'un melange de dioxyde de carbone gazeux par la recuperation du petrole assistee par vapeur
PCT/US2011/027574 WO2012121710A1 (fr) 2011-03-07 2011-03-08 Traitement d'un mélange de dioxyde de carbone gazeux par la récupération du pétrole assistée par vapeur

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Application Number Priority Date Filing Date Title
US13/042,096 US20120227964A1 (en) 2011-03-07 2011-03-07 Carbon dioxide gas mixture processing with steam assisted oil recovery

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CA (1) CA2827765A1 (fr)
WO (1) WO2012121710A1 (fr)

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2014205208A1 (fr) * 2013-06-21 2014-12-24 Conocophillips Company Chaudière à oxygène à production assistée par vapeur
WO2015020850A1 (fr) * 2013-08-05 2015-02-12 Conocophillips Company Génération de vapeur à l'aide du recyclage de dioxyde de carbone
US11125063B2 (en) 2017-07-19 2021-09-21 Conocophillips Company Accelerated interval communication using openholes
US11156072B2 (en) 2016-08-25 2021-10-26 Conocophillips Company Well configuration for coinjection
US11668176B2 (en) 2016-08-25 2023-06-06 Conocophillips Company Well configuration for coinjection

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* Cited by examiner, † Cited by third party
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US2039330A (en) * 1930-07-08 1936-05-05 Ralph H Mckee Purification of carbon dioxide
US2734578A (en) * 1956-02-14 Walter
US3344856A (en) * 1964-03-26 1967-10-03 Deutsche Erdoel Ag Process for the extraction of liquid and solid bitumens from underground deposits
US3360044A (en) * 1963-03-21 1967-12-26 Deutsche Erdoel Ag Process and apparatus for the recovery of liquid bitumen from underground deposits
US3442332A (en) * 1966-02-01 1969-05-06 Percival C Keith Combination methods involving the making of gaseous carbon dioxide and its use in crude oil recovery
US4099568A (en) * 1974-02-15 1978-07-11 Texaco Inc. Method for recovering viscous petroleum
US4330038A (en) * 1980-05-14 1982-05-18 Zimpro-Aec Ltd. Oil reclamation process
US4344486A (en) * 1981-02-27 1982-08-17 Standard Oil Company (Indiana) Method for enhanced oil recovery
US4417449A (en) * 1982-01-15 1983-11-29 Air Products And Chemicals, Inc. Process for separating carbon dioxide and acid gases from a carbonaceous off-gas
US4434613A (en) * 1981-09-02 1984-03-06 General Electric Company Closed cycle gas turbine for gaseous production
US4480696A (en) * 1982-10-25 1984-11-06 Halliburton Company Fracturing method for stimulation of wells utilizing carbon dioxide based fluids
US4664190A (en) * 1985-12-18 1987-05-12 Shell Western E&P Inc. Process for recovering natural gas liquids
US20020036086A1 (en) * 2000-04-27 2002-03-28 Institut Francais Du Petrole Process for purification by combination of an effluent that contains carbon dioxide and hydrocarbons
US20040050067A1 (en) * 2002-09-12 2004-03-18 The Boeing Company Low-emission, staged-combustion power generation
US20060243448A1 (en) * 2005-04-28 2006-11-02 Steve Kresnyak Flue gas injection for heavy oil recovery
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US20080257543A1 (en) * 2007-01-19 2008-10-23 Errico De Francesco Process and apparatus for enhanced hydrocarbon recovery
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US20090292571A1 (en) * 2008-05-20 2009-11-26 Osum Oil Sands Corp. Method of managing carbon reduction for hydrocarbon producers
US7770640B2 (en) * 2006-02-07 2010-08-10 Diamond Qc Technologies Inc. Carbon dioxide enriched flue gas injection for hydrocarbon recovery
US20100242811A1 (en) * 2007-11-26 2010-09-30 L'air Liquids Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Adapting Of An Oxy-Combustion Plant To Energy Availability And To The Amount Of CO2 To Be Trapped

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20080078552A1 (en) * 2006-09-29 2008-04-03 Osum Oil Sands Corp. Method of heating hydrocarbons
US8561702B2 (en) * 2007-02-10 2013-10-22 Vast Power Portfolio, Llc Hot fluid recovery of heavy oil with steam and carbon dioxide
US8091636B2 (en) * 2008-04-30 2012-01-10 World Energy Systems Incorporated Method for increasing the recovery of hydrocarbons
CA2692989C (fr) * 2009-02-20 2015-12-01 Conocophillips Company Production de vapeur pour recuperation de petrole au moyen de vapeur

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US2734578A (en) * 1956-02-14 Walter
US2039330A (en) * 1930-07-08 1936-05-05 Ralph H Mckee Purification of carbon dioxide
US3360044A (en) * 1963-03-21 1967-12-26 Deutsche Erdoel Ag Process and apparatus for the recovery of liquid bitumen from underground deposits
US3344856A (en) * 1964-03-26 1967-10-03 Deutsche Erdoel Ag Process for the extraction of liquid and solid bitumens from underground deposits
US3442332A (en) * 1966-02-01 1969-05-06 Percival C Keith Combination methods involving the making of gaseous carbon dioxide and its use in crude oil recovery
US4099568A (en) * 1974-02-15 1978-07-11 Texaco Inc. Method for recovering viscous petroleum
US4330038A (en) * 1980-05-14 1982-05-18 Zimpro-Aec Ltd. Oil reclamation process
US4344486A (en) * 1981-02-27 1982-08-17 Standard Oil Company (Indiana) Method for enhanced oil recovery
US4434613A (en) * 1981-09-02 1984-03-06 General Electric Company Closed cycle gas turbine for gaseous production
US4417449A (en) * 1982-01-15 1983-11-29 Air Products And Chemicals, Inc. Process for separating carbon dioxide and acid gases from a carbonaceous off-gas
US4480696A (en) * 1982-10-25 1984-11-06 Halliburton Company Fracturing method for stimulation of wells utilizing carbon dioxide based fluids
US4664190A (en) * 1985-12-18 1987-05-12 Shell Western E&P Inc. Process for recovering natural gas liquids
US20020036086A1 (en) * 2000-04-27 2002-03-28 Institut Francais Du Petrole Process for purification by combination of an effluent that contains carbon dioxide and hydrocarbons
US7320288B2 (en) * 2002-02-15 2008-01-22 American Air Liquide, Inc. Steam-generating combustion system and method for emission control using oxygen enhancement
US20040050067A1 (en) * 2002-09-12 2004-03-18 The Boeing Company Low-emission, staged-combustion power generation
US20060243448A1 (en) * 2005-04-28 2006-11-02 Steve Kresnyak Flue gas injection for heavy oil recovery
US7341102B2 (en) * 2005-04-28 2008-03-11 Diamond Qc Technologies Inc. Flue gas injection for heavy oil recovery
US7770640B2 (en) * 2006-02-07 2010-08-10 Diamond Qc Technologies Inc. Carbon dioxide enriched flue gas injection for hydrocarbon recovery
US20070231244A1 (en) * 2006-04-03 2007-10-04 Shah Minish M Carbon dioxide purification method
US20070248527A1 (en) * 2006-04-25 2007-10-25 Spencer Dwain F Methods and systems for selectively separating co2 from an oxygen combustion gaseous stream
US20070261844A1 (en) * 2006-05-10 2007-11-15 Raytheon Company Method and apparatus for capture and sequester of carbon dioxide and extraction of energy from large land masses during and after extraction of hydrocarbon fuels or contaminants using energy and critical fluids
US20100083666A1 (en) * 2006-12-18 2010-04-08 Peter Holroyd Brook Process
WO2008074980A1 (fr) * 2006-12-18 2008-06-26 Hydrogen Energy International Limited Procédé
US20080257543A1 (en) * 2007-01-19 2008-10-23 Errico De Francesco Process and apparatus for enhanced hydrocarbon recovery
US7866389B2 (en) * 2007-01-19 2011-01-11 L'air Liquide Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Process and apparatus for enhanced hydrocarbon recovery
US20080236812A1 (en) * 2007-03-30 2008-10-02 Fengshan Zhang Oil recovery by injection of steam, carbon dioxide and nitrogen
US20080289821A1 (en) * 2007-05-23 2008-11-27 Betzer Tsilevich Maoz Integrated system and method for steam-assisted gravity drainage (sagd)-heavy oil production using low quality fuel and low quality water
US20100242811A1 (en) * 2007-11-26 2010-09-30 L'air Liquids Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Adapting Of An Oxy-Combustion Plant To Energy Availability And To The Amount Of CO2 To Be Trapped
US20090292571A1 (en) * 2008-05-20 2009-11-26 Osum Oil Sands Corp. Method of managing carbon reduction for hydrocarbon producers

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2014205208A1 (fr) * 2013-06-21 2014-12-24 Conocophillips Company Chaudière à oxygène à production assistée par vapeur
WO2015020850A1 (fr) * 2013-08-05 2015-02-12 Conocophillips Company Génération de vapeur à l'aide du recyclage de dioxyde de carbone
US11156072B2 (en) 2016-08-25 2021-10-26 Conocophillips Company Well configuration for coinjection
US11668176B2 (en) 2016-08-25 2023-06-06 Conocophillips Company Well configuration for coinjection
US11125063B2 (en) 2017-07-19 2021-09-21 Conocophillips Company Accelerated interval communication using openholes

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Publication number Publication date
CA2827765A1 (fr) 2012-09-13
WO2012121710A1 (fr) 2012-09-13

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