CA2827765A1 - Carbon dioxide gas mixture processing with steam assisted oil recovery - Google Patents
Carbon dioxide gas mixture processing with steam assisted oil recovery Download PDFInfo
- Publication number
- CA2827765A1 CA2827765A1 CA2827765A CA2827765A CA2827765A1 CA 2827765 A1 CA2827765 A1 CA 2827765A1 CA 2827765 A CA2827765 A CA 2827765A CA 2827765 A CA2827765 A CA 2827765A CA 2827765 A1 CA2827765 A1 CA 2827765A1
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- 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.)
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- 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 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
- E21B43/24—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
Abstract
Methods and apparatus relate to 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.
Description
CARBON DIOXIDE GAS MIXTURE PROCESSING WITH STEAM ASSISTED OIL
RECOVERY
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] None STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR
DEVELOPMENT
RECOVERY
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] None STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR
DEVELOPMENT
[0002] None FIELD OF THE INVENTION
[0003] 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.
BACKGROUND OF THE INVENTION
BACKGROUND OF THE INVENTION
[0004] 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.
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.
[0005] 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.
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.
[0006] 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.
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.
[0007] Therefore, a need exists for improved methods and systems for processing carbon dioxide for capture.
SUMMARY OF THE INVENTION
SUMMARY OF THE INVENTION
[0008] In one embodiment, 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.
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.
[0009] According to one embodiment, 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. In addition, 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.
[0010] For one embodiment, 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.
BRIEF DESCRIPTION OF THE DRAWINGS
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.
BRIEF DESCRIPTION OF THE DRAWINGS
[0011] The invention, together with further advantages thereof, may best be understood by reference to the following description taken in conjunction with the accompanying drawings.
[0012] Figure 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.
DETAILED DESCRIPTION OF THE INVENTION
DETAILED DESCRIPTION OF THE INVENTION
[0013] 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.
[0014] Figure 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.
[0015] 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.
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.
[0016] For some embodiments, 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.
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.
[0017] In operation, the mixture makes the petroleum products mobile enough to enable or facilitate recovery with, for example, the production well 102. For some embodiments, 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.
[0018] 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.
[0019] In some embodiments, 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. Likewise, 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.
[0020] As a benefit to recovery, 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. Unlike loss of carbon dioxide associated with cleaning of the flue gas 107 above ground to remove oxygen, the carbon dioxide being held in the formation 103 remains sequestered without requiring any additional treatment to be captured.
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. Unlike loss of carbon dioxide associated with cleaning of the flue gas 107 above ground to remove oxygen, the carbon dioxide being held in the formation 103 remains sequestered without requiring any additional treatment to be captured.
[0021] 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.
[0022] Due to the oxidation reactions discussed herein, 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. In some embodiments, 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.
[0023] This reduction in oxygen content processes the carbon dioxide to enable transporting the carbon dioxide without further oxygen removal from the vapor phase 112. For some embodiments, 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.
[0024] In some embodiments, 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. If only such scrubbing of the flue gas 107 and not recovering of the petroleum products is desired, some embodiments may inject the flue gas 107 without mixing the flue gas 107 with the steam 105.
[0025] The preferred embodiment of the present invention has been disclosed and illustrated. However, the invention is intended to be as broad as defined in the claims below.
Those skilled in the art may be able to study the preferred embodiments and identify other ways to practice the invention that are not exactly as described herein. It is the intent of the inventors that variations and equivalents of the invention are within the scope of the claims below and the description, abstract and drawings are not to be used to limit the scope of the invention.
Those skilled in the art may be able to study the preferred embodiments and identify other ways to practice the invention that are not exactly as described herein. It is the intent of the inventors that variations and equivalents of the invention are within the scope of the claims below and the description, abstract and drawings are not to be used to limit the scope of the invention.
Claims (20)
1. A method, comprising:
forming a mixture of flue gas from oxy-fuel combustion and steam generated prior to being mixed with the flue gas, wherein 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 for heating oil in the formation and reacting with the oil at least some of the oxygen that is from the flue gas and is dissolved in liquid condensate of the steam;
recovering fluids including the oil that is heated and the carbon dioxide from the flue gas;
separating the fluids recovered to isolate from a liquid phase the carbon dioxide containing less than the initial concentration of oxygen; and transporting to a sequestration site the carbon dioxide that is separated from the liquid phase.
forming a mixture of flue gas from oxy-fuel combustion and steam generated prior to being mixed with the flue gas, wherein 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 for heating oil in the formation and reacting with the oil at least some of the oxygen that is from the flue gas and is dissolved in liquid condensate of the steam;
recovering fluids including the oil that is heated and the carbon dioxide from the flue gas;
separating the fluids recovered to isolate from a liquid phase the carbon dioxide containing less than the initial concentration of oxygen; and transporting to a sequestration site the carbon dioxide that is separated from the liquid phase.
2. The method according to claim 1, further comprising heating a boiler for generating the steam using the oxy-fuel combustion.
3. The method according to claim 1, wherein the oxy-fuel combustion is part of a heating unit separate from a steam generator that makes the steam.
4. The method according to claim 1, wherein the separating the fluids removes the liquid phase from a vapor phase that is at least 95% carbon dioxide by volume.
5. The method according to claim 1, wherein the separating the fluids removes the liquid phase from a vapor phase that is at least 95% carbon dioxide by volume with oxygen content of less than 0.001% by volume.
6. The method according to claim 1, wherein the reacting of the oil with at least some of the oxygen is at a temperature of at least 100° C.
7 7. The method according to claim 1, wherein the reacting of the oil with at least some of the oxygen is at a temperature of at least 200° C.
8. The method according to claim 1, wherein at least 90% by volume of the flue gas is the carbon dioxide.
9. The method according to claim 1, further comprising adding to the mixture a hydrocarbon-containing solvent for the oil being produced and having a lower viscosity than the oil being produced.
10. The method according to claim 1, wherein the transporting includes passing the carbon dioxide through a pipeline.
11. The method according to claim 1, wherein the injecting is through a first wellbore spaced from a second wellbore located deeper in the formation than the first wellbore and through which the recovering occurs.
12. A method, comprising:
producing flue gas from oxy-fuel combustion, wherein the flue gas contains carbon dioxide with quantities of oxygen greater than a transport specification;
generating steam without contact of the steam with the flue gas;
introducing the steam into the flue gas to form a mixture;
injecting the mixture into a formation for heating oil in the formation;
recovering fluids including the oil that is heated and the carbon dioxide from the flue gas;
separating the fluids into liquids and vapors, which are formed of the carbon dioxide and 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; and transporting to a sequestration site the carbon dioxide obtained by the separating.
producing flue gas from oxy-fuel combustion, wherein the flue gas contains carbon dioxide with quantities of oxygen greater than a transport specification;
generating steam without contact of the steam with the flue gas;
introducing the steam into the flue gas to form a mixture;
injecting the mixture into a formation for heating oil in the formation;
recovering fluids including the oil that is heated and the carbon dioxide from the flue gas;
separating the fluids into liquids and vapors, which are formed of the carbon dioxide and 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; and transporting to a sequestration site the carbon dioxide obtained by the separating.
13. The method according to claim 12, wherein the transportation specification is oxygen content of less than 0.001% by volume.
14. The method according to claim 12, wherein the separating the fluids removes the liquids from the vapors that are at least 95% carbon dioxide by volume.
15. The method according to claim 12, wherein the oxy-fuel combustion is used to heat a boiler for the generating of the steam.
16. The method according to claim 12, wherein at least 90% by volume of the flue gas is the carbon dioxide and at least 0.1% by volume of the flue gas is the oxygen.
17. The method according to claim 12, wherein the transporting includes passing the carbon dioxide through a pipeline.
18. The method according to claim 12, wherein the elevated temperatures are above 150° C.
19. A system, comprising:
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;
an injection well disposed in a subterranean formation containing oil, wherein the injection well is coupled in fluid communication with the supply of the flue gas and the source of the steam; and a vapor-liquid separator coupled to receive produced fluids heated by the steam and output carbon dioxide from the flue gas, wherein the carbon dioxide in the produced fluids 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.
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;
an injection well disposed in a subterranean formation containing oil, wherein the injection well is coupled in fluid communication with the supply of the flue gas and the source of the steam; and a vapor-liquid separator coupled to receive produced fluids heated by the steam and output carbon dioxide from the flue gas, wherein the carbon dioxide in the produced fluids 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.
20. The system according to claim 19, wherein the oxy-fuel combustion chamber is coupled to heat a boiler for generating the steam.
Applications Claiming Priority (3)
| 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 |
| PCT/US2011/027574 WO2012121710A1 (en) | 2011-03-07 | 2011-03-08 | Carbon dioxide gas mixture processing with steam assisted oil recovery |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2827765A1 true CA2827765A1 (en) | 2012-09-13 |
Family
ID=46794471
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2827765A Abandoned CA2827765A1 (en) | 2011-03-07 | 2011-03-08 | Carbon dioxide gas mixture processing with steam assisted oil recovery |
Country Status (3)
| Country | Link |
|---|---|
| US (1) | US20120227964A1 (en) |
| CA (1) | CA2827765A1 (en) |
| WO (1) | WO2012121710A1 (en) |
Families Citing this family (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2014205208A1 (en) * | 2013-06-21 | 2014-12-24 | Conocophillips Company | Oxy-boiler with steam assisted production |
| WO2015020850A1 (en) * | 2013-08-05 | 2015-02-12 | Conocophillips Company | Steam generation with carbon dioxide recycle |
| US11156072B2 (en) | 2016-08-25 | 2021-10-26 | Conocophillips Company | Well configuration for coinjection |
| CA2976575A1 (en) | 2016-08-25 | 2018-02-25 | Conocophillips Company | Well configuration for coinjection |
| CA3011861C (en) | 2017-07-19 | 2020-07-21 | Conocophillips Company | Accelerated interval communication using open-holes |
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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 (en) * | 1963-03-21 | 1966-05-18 | Deutsche Erdoel Ag | Method and device for conveying liquid bitumen from underground storage areas |
| DE1241776B (en) * | 1964-03-26 | 1967-06-08 | Deutsche Erdoel Ag | Process for the extraction of bitumina from deposits by in-situ incineration |
| 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 |
| CA1028943A (en) * | 1974-02-15 | 1978-04-04 | Texaco Development Corporation | 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 |
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| 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 (en) * | 2007-11-26 | 2010-04-02 | Air Liquide | ADAPTATION OF AN OXYCOMBUSTION PLANT TO THE AVAILABILITY OF ENERGY AND THE QUANTITY OF CO2 TO CAPTURATE |
| US8091636B2 (en) * | 2008-04-30 | 2012-01-10 | World Energy Systems Incorporated | Method for increasing the recovery of hydrocarbons |
| CA2718885C (en) * | 2008-05-20 | 2014-05-06 | Osum Oil Sands Corp. | Method of managing carbon reduction for hydrocarbon producers |
| CA2692989C (en) * | 2009-02-20 | 2015-12-01 | Conocophillips Company | Steam generation for steam assisted oil recovery |
-
2011
- 2011-03-07 US US13/042,096 patent/US20120227964A1/en not_active Abandoned
- 2011-03-08 CA CA2827765A patent/CA2827765A1/en not_active Abandoned
- 2011-03-08 WO PCT/US2011/027574 patent/WO2012121710A1/en active Application Filing
Also Published As
| Publication number | Publication date |
|---|---|
| US20120227964A1 (en) | 2012-09-13 |
| WO2012121710A1 (en) | 2012-09-13 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request |
Effective date: 20160304 |
|
| FZDE | Discontinued |
Effective date: 20190530 |