WO2012121710A1 - Traitement d'un mélange de dioxyde de carbone gazeux par la récupération du pétrole assistée par vapeur - Google Patents
Traitement d'un mélange de dioxyde de carbone gazeux par la récupération du pétrole assistée par vapeur Download PDFInfo
- Publication number
- WO2012121710A1 WO2012121710A1 PCT/US2011/027574 US2011027574W WO2012121710A1 WO 2012121710 A1 WO2012121710 A1 WO 2012121710A1 US 2011027574 W US2011027574 W US 2011027574W WO 2012121710 A1 WO2012121710 A1 WO 2012121710A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- flue gas
- carbon dioxide
- steam
- oxygen
- oil
- Prior art date
Links
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 title claims abstract description 116
- 239000001569 carbon dioxide Substances 0.000 title claims abstract description 58
- 229910002092 carbon dioxide Inorganic materials 0.000 title claims abstract description 58
- 239000000203 mixture Substances 0.000 title claims description 16
- 238000011084 recovery Methods 0.000 title abstract description 9
- 238000012545 processing Methods 0.000 title abstract description 7
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims abstract description 77
- 239000003546 flue gas Substances 0.000 claims abstract description 77
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims abstract description 50
- 239000001301 oxygen Substances 0.000 claims abstract description 50
- 229910052760 oxygen Inorganic materials 0.000 claims abstract description 50
- 238000000034 method Methods 0.000 claims abstract description 28
- 238000002485 combustion reaction Methods 0.000 claims abstract description 27
- 239000000446 fuel Substances 0.000 claims abstract description 27
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 20
- 239000012530 fluid Substances 0.000 claims abstract description 20
- 238000002347 injection Methods 0.000 claims abstract description 20
- 239000007924 injection Substances 0.000 claims abstract description 20
- 239000007791 liquid phase Substances 0.000 claims description 13
- 239000012808 vapor phase Substances 0.000 claims description 10
- 239000007788 liquid Substances 0.000 claims description 9
- 238000010438 heat treatment Methods 0.000 claims description 8
- 238000006243 chemical reaction Methods 0.000 claims description 7
- 230000009919 sequestration Effects 0.000 claims description 7
- 238000007254 oxidation reaction Methods 0.000 claims description 6
- 230000003647 oxidation Effects 0.000 claims description 5
- 239000002904 solvent Substances 0.000 claims description 5
- 229930195733 hydrocarbon Natural products 0.000 claims description 4
- 150000002430 hydrocarbons Chemical class 0.000 claims description 4
- 239000004215 Carbon black (E152) Substances 0.000 claims description 2
- 238000004891 communication Methods 0.000 claims description 2
- 239000003921 oil Substances 0.000 description 14
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 10
- 238000004519 manufacturing process Methods 0.000 description 8
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 6
- 239000003209 petroleum derivative Substances 0.000 description 5
- 239000007789 gas Substances 0.000 description 4
- 239000003345 natural gas Substances 0.000 description 4
- VLKZOEOYAKHREP-UHFFFAOYSA-N n-Hexane Chemical compound CCCCCC VLKZOEOYAKHREP-UHFFFAOYSA-N 0.000 description 3
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 3
- 229910052757 nitrogen Inorganic materials 0.000 description 3
- MYMOFIZGZYHOMD-UHFFFAOYSA-N Dioxygen Chemical compound O=O MYMOFIZGZYHOMD-UHFFFAOYSA-N 0.000 description 2
- IMNFDUFMRHMDMM-UHFFFAOYSA-N N-Heptane Chemical compound CCCCCCC IMNFDUFMRHMDMM-UHFFFAOYSA-N 0.000 description 2
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 2
- 238000010796 Steam-assisted gravity drainage Methods 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 230000003993 interaction Effects 0.000 description 2
- 238000002156 mixing Methods 0.000 description 2
- 239000012071 phase Substances 0.000 description 2
- 238000000926 separation method Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Chemical compound O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 1
- 238000013459 approach Methods 0.000 description 1
- 239000010426 asphalt Substances 0.000 description 1
- 239000001273 butane Substances 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 239000003245 coal Substances 0.000 description 1
- 239000000567 combustion gas Substances 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000004821 distillation Methods 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 239000012535 impurity Substances 0.000 description 1
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 1
- -1 naphtha Chemical compound 0.000 description 1
- 239000003498 natural gas condensate Substances 0.000 description 1
- 239000002006 petroleum coke Substances 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 239000001294 propane Substances 0.000 description 1
- 238000000746 purification Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 230000000630 rising effect Effects 0.000 description 1
- 238000005201 scrubbing Methods 0.000 description 1
- 238000004326 stimulated echo acquisition mode for imaging Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—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.
- 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 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.
- 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.
- 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.
- 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.
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Treating Waste Gases (AREA)
- Carbon And Carbon Compounds (AREA)
- Gas Separation By Absorption (AREA)
Abstract
Les présents procédés et dispositif concernent le traitement des effluents gazeux de l'oxycombustion. La vapeur générée sans contact de la vapeur avec des effluents gazeux est combinée aux effluents gazeux pour injection dans une formation, pour faciliter la récupération du pétrole de ladite formation. Les fluides produits incluent le pétrole et du dioxyde de carbone de concentration en oxygène inférieure à celle des effluents gazeux injectés.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
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 |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/042,096 | 2011-03-07 | ||
US13/042,096 US20120227964A1 (en) | 2011-03-07 | 2011-03-07 | Carbon dioxide gas mixture processing with steam assisted oil recovery |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2012121710A1 true WO2012121710A1 (fr) | 2012-09-13 |
Family
ID=46794471
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
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 |
Country Status (3)
Country | Link |
---|---|
US (1) | US20120227964A1 (fr) |
CA (1) | CA2827765A1 (fr) |
WO (1) | WO2012121710A1 (fr) |
Families Citing this family (5)
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 |
CA2976575A1 (fr) | 2016-08-25 | 2018-02-25 | Conocophillips Company | Configuration de puits en vue de la coinjection |
US11156072B2 (en) | 2016-08-25 | 2021-10-26 | Conocophillips Company | Well configuration for coinjection |
CA3011861C (fr) | 2017-07-19 | 2020-07-21 | Conocophillips Company | Communication a intervalle accelere au moyen de trous ouverts |
Citations (8)
Publication number | Priority date | Publication date | Assignee | Title |
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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 |
US7341102B2 (en) * | 2005-04-28 | 2008-03-11 | Diamond Qc Technologies Inc. | Flue gas injection for heavy oil recovery |
US20080257543A1 (en) * | 2007-01-19 | 2008-10-23 | Errico De Francesco | Process and apparatus for enhanced hydrocarbon recovery |
US20090272532A1 (en) * | 2008-04-30 | 2009-11-05 | Kuhlman Myron I | Method for increasing the recovery of hydrocarbons |
US20100212894A1 (en) * | 2009-02-20 | 2010-08-26 | Conocophillips Company | Steam generation for steam assisted oil recovery |
US20100224370A1 (en) * | 2006-09-29 | 2010-09-09 | Osum Oil Sands Corp | Method of heating hydrocarbons |
US20100276148A1 (en) * | 2007-02-10 | 2010-11-04 | Vast Power Portfolio, Llc | Hot fluid recovery of heavy oil with steam and carbon dioxide |
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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 |
DE1216817B (de) * | 1963-03-21 | 1966-05-18 | Deutsche Erdoel Ag | Verfahren und Vorrichtung zum Foerdern von fluessiger Bitumina aus untertaegigen Lagerstaetten |
DE1241776B (de) * | 1964-03-26 | 1967-06-08 | Deutsche Erdoel Ag | Verfahren zum Foerdern von Bitumina aus Lagerstaetten durch in-situ-Verbrennung |
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 |
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 |
FR2808223B1 (fr) * | 2000-04-27 | 2002-11-22 | Inst Francais Du Petrole | Procede de purification d'un effluent contenant du gaz carbonique et des hydrocarbures par combustion |
US6935251B2 (en) * | 2002-02-15 | 2005-08-30 | American Air Liquide, Inc. | Steam-generating combustion system and method for emission control using oxygen enhancement |
US6775987B2 (en) * | 2002-09-12 | 2004-08-17 | The Boeing Company | Low-emission, staged-combustion power generation |
ATE491861T1 (de) * | 2006-02-07 | 2011-01-15 | Diamond Qc Technologies Inc | Mit kohlendioxid angereicherte rauchgaseinspritzung zur kohlenwasserstoffgewinnung |
US7666251B2 (en) * | 2006-04-03 | 2010-02-23 | Praxair Technology, Inc. | 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 |
US7562708B2 (en) * | 2006-05-10 | 2009-07-21 | 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 |
EP1944268A1 (fr) * | 2006-12-18 | 2008-07-16 | BP Alternative Energy Holdings Limited | Processus |
CN201031675Y (zh) * | 2007-03-30 | 2008-03-05 | 辽河石油勘探局 | 蒸汽二氧化碳氮气联注采油装置 |
US7699104B2 (en) * | 2007-05-23 | 2010-04-20 | Maoz Betzer Tsilevich | Integrated system and method for steam-assisted gravity drainage (SAGD)-heavy oil production using low quality fuel and low quality water |
FR2924203B1 (fr) * | 2007-11-26 | 2010-04-02 | Air Liquide | Adaptation d'une centrale a oxycombustion a la disponibilite de l'energie et a la quantite de co2 a capturer |
US8209192B2 (en) * | 2008-05-20 | 2012-06-26 | Osum Oil Sands Corp. | Method of managing carbon reduction for hydrocarbon producers |
-
2011
- 2011-03-07 US US13/042,096 patent/US20120227964A1/en not_active Abandoned
- 2011-03-08 WO PCT/US2011/027574 patent/WO2012121710A1/fr active Application Filing
- 2011-03-08 CA CA2827765A patent/CA2827765A1/fr not_active Abandoned
Patent Citations (8)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
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 |
US7341102B2 (en) * | 2005-04-28 | 2008-03-11 | Diamond Qc Technologies Inc. | Flue gas injection for heavy oil recovery |
US20100224370A1 (en) * | 2006-09-29 | 2010-09-09 | Osum Oil Sands Corp | Method of heating hydrocarbons |
US20080257543A1 (en) * | 2007-01-19 | 2008-10-23 | Errico De Francesco | Process and apparatus for enhanced hydrocarbon recovery |
US20100276148A1 (en) * | 2007-02-10 | 2010-11-04 | Vast Power Portfolio, Llc | Hot fluid recovery of heavy oil with steam and carbon dioxide |
US20090272532A1 (en) * | 2008-04-30 | 2009-11-05 | Kuhlman Myron I | Method for increasing the recovery of hydrocarbons |
US20100212894A1 (en) * | 2009-02-20 | 2010-08-26 | Conocophillips Company | Steam generation for steam assisted oil recovery |
Also Published As
Publication number | Publication date |
---|---|
US20120227964A1 (en) | 2012-09-13 |
CA2827765A1 (fr) | 2012-09-13 |
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