IPC분류정보
국가/구분 |
United States(US) Patent
등록
|
국제특허분류(IPC7판) |
|
출원번호 |
UP-0016829
(2008-01-18)
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등록번호 |
US-7712528
(2010-06-03)
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발명자
/ 주소 |
- Langdon, John E.
- Ware, Charles H.
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출원인 / 주소 |
- World Energy Systems, Inc.
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대리인 / 주소 |
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인용정보 |
피인용 횟수 :
35 인용 특허 :
23 |
초록
▼
Embodiments include methods for recovering petroleum products from a formation containing heavy crude oil. In one embodiment, a method includes flowing a catalytic material containing the nanocatalyst into the formation containing the heavy crude oil and exposing the heavy crude oil and the catalyti
Embodiments include methods for recovering petroleum products from a formation containing heavy crude oil. In one embodiment, a method includes flowing a catalytic material containing the nanocatalyst into the formation containing the heavy crude oil and exposing the heavy crude oil and the catalytic material to a reducing agent (e.g., H2). The method further includes positioning a steam generator within the formation, generating and releasing steam from the steam generator to heat the heavy crude oil containing the catalytic material, forming lighter oil products within the formation, and extracting the lighter oil products from the formation. In another embodiment, a method includes exposing the heavy crude oil and the catalytic material to an oxidizing agent (e.g., O2). The nanocatalyst may contain cobalt, iron, nickel, molybdenum, chromium, tungsten, titanium, oxides thereof, alloys thereof, or combinations thereof.
대표청구항
▼
The invention claimed is: 1. A method for recovering petroleum products from a petroleum-bearing formation, comprising: flowing a catalytic material comprising a nanocatalyst into a formation comprising a heavy crude oil; exposing the heavy crude oil and the catalytic material to a reducing agent;
The invention claimed is: 1. A method for recovering petroleum products from a petroleum-bearing formation, comprising: flowing a catalytic material comprising a nanocatalyst into a formation comprising a heavy crude oil; exposing the heavy crude oil and the catalytic material to a reducing agent; positioning a steam generator within the formation; generating and releasing steam from the steam generator to heat the heavy crude oil comprising the catalytic material; forming lighter oil products from the heavy crude oil within the formation; and extracting the lighter oil products from the formation. 2. The method of claim 1, wherein the nanocatalyst comprises a metal selected from the group consisting of iron, nickel, molybdenum, tungsten, titanium, vanadium, chromium, manganese, cobalt, alloys thereof, oxides thereof, sulfides thereof, derivatives thereof, and combinations thereof. 3. The method of claim 2, wherein the nanocatalyst comprises iron and a metal selected from the group consisting of nickel, molybdenum, tungsten, titanium, vanadium, chromium, manganese, cobalt, alloys thereof, oxides thereof, sulfides thereof, derivatives thereof, and combinations thereof. 4. The method of claim 3, wherein the nanocatalyst comprises iron, nickel, and molybdenum. 5. The method of claim 2, wherein the nanocatalyst comprises a nickel compound and a molybdenum compound. 6. The method of claim 2, wherein the nanocatalyst comprises a cobalt compound and a molybdenum compound. 7. The method of claim 2, wherein the nanocatalyst comprises tungsten oxide, tungsten sulfide, derivatives thereof, or combinations thereof. 8. The method of claim 2, wherein the catalytic material comprises the nanocatalyst supported on carbon nanoparticulate. 9. The method of claim 8, wherein the carbon nanoparticulate has a diameter of less than 1 μm. 10. The method of claim 9, wherein the diameter is within a range from about 5 nm to about 500 nm. 11. The method of claim 2, wherein the catalytic material comprises the nanocatalyst supported on alumina, silica, molecular sieves, ceramic materials, derivatives thereof, or combinations thereof. 12. The method of claim 1, wherein the heavy crude oil comprising the catalytic material is heated by the steam to a temperature of less than about 600° F. 13. The method of claim 12, wherein the temperature is within a range from about 250° F. to about 580° F. 14. The method of claim 13, wherein the temperature is within a range from about 400° F. to about 550° F. 15. The method of claim 1, wherein the reducing agent comprises a reagent selected from the group consisting of hydrogen gas, carbon monoxide, synthetic gas, tetralin, decalin, derivatives thereof, and combinations thereof. 16. The method of claim 15, wherein the catalytic material and the reducing agent are co-flowed into the formation. 17. The method of claim 16, wherein the reducing agent comprises hydrogen gas. 18. The method of claim 17, wherein the hydrogen gas has a partial pressure of about 100 psi or greater within the formation. 19. The method of claim 1, wherein the steam is generated by combusting oxygen gas and hydrogen gas within the steam generator. 20. The method of claim 19, wherein the oxygen gas and the hydrogen gas are each transferred from outside of the formation, through a borehole, and into the formation. 21. The method of claim 1, wherein the steam is generated by combusting oxygen gas and a hydrocarbon gas within the steam generator. 22. The method of claim 21, wherein the oxygen gas and the hydrocarbon gas are each transferred from outside of the formation, through a borehole, and into the formation. 23. The method of claim 22, wherein the hydrocarbon gas comprises methane. 24. The method of claim 1, further comprising reducing viscosity of the heavy crude oil by exposing the heavy crude oil and the catalytic material to carbon dioxide. 25. The method of claim 24, wherein the carbon dioxide is transferred from outside of the formation, through a borehole, and into the formation. 26. The method of claim 1, wherein the lighter oil products comprise a lower concentration of a sulfur impurity than the heavy crude oil. 27. The method of claim 26, wherein the lighter oil products comprise about 50% by weight or less of the sulfur impurity than the heavy crude oil. 28. The method of claim 27, wherein the lighter oil products comprise about 30% by weight or less of the sulfur impurity than the heavy crude oil. 29. A method for recovering petroleum products from a petroleum-bearing formation, comprising: flowing a catalytic material comprising a nanocatalyst into a formation comprising a heavy crude oil; exposing the heavy crude oil and the catalytic material to an oxidizing agent; positioning a steam generator within the formation; generating and releasing steam from the steam generator to heat the heavy crude oil comprising the catalytic material; forming lighter oil products from the heavy crude oil within the formation; and extracting the lighter oil products from the formation. 30. The method of claim 29, wherein the nanocatalyst comprises a member selected from the group consisting of titanium, zirconium, aluminum, silicon, oxides thereof, alloys thereof, derivatives thereof, and combinations thereof. 31. The method of claim 30, wherein the nanocatalyst comprises titanium oxide. 32. The method of claim 30, wherein the catalytic material comprises the nanocatalyst supported on carbon nanotubes. 33. The method of claim 30, wherein the catalytic material comprises the nanocatalyst supported on alumina, silica, molecular sieves, ceramic materials, derivatives thereof, or combinations thereof. 34. The method of claim 29, wherein the heavy crude oil comprising the catalytic material is heated by the steam to a temperature of less than about 600° F. 35. The method of claim 34, wherein the temperature is within a range from about 250° F. to about 580° F. 36. The method of claim 35, wherein the temperature is within a range from about 400° F. to about 550° F. 37. The method of claim 29, wherein the oxidizing agent comprises a reagent selected from the group consisting of oxygen gas, air, oxygen enriched air, hydrogen peroxide solution, derivatives thereof, and combinations thereof. 38. The method of claim 37, wherein the catalytic material and the oxidizing agent are co-flowed into the formation. 39. The method of claim 38, wherein the oxidizing agent comprises oxygen gas. 40. The method of claim 29, wherein the steam is generated by combusting oxygen gas and hydrogen gas within the steam generator. 41. The method of claim 40, wherein the oxygen gas and the hydrogen gas are each transferred from outside of the formation, through a borehole, and into the formation. 42. The method of claim 29, wherein the steam is generated by combusting oxygen gas and a hydrocarbon gas within the steam generator. 43. The method of claim 42, wherein the oxygen gas and the hydrocarbon gas are each transferred from outside of the formation, through a borehole, and into the formation. 44. The method of claim 43, wherein the hydrocarbon gas comprises methane. 45. The method of claim 29, further comprising reducing viscosity of the heavy crude oil by exposing the heavy crude oil and the catalytic material to carbon dioxide. 46. The method of claim 45, wherein the carbon dioxide is transferred from outside of the formation, through a borehole, and into the formation. 47. The method of claim 29, wherein the lighter oil products comprise a lower concentration of a sulfur impurity than the heavy crude oil. 48. The method of claim 47, wherein the lighter oil products comprise about 50% by weight or less of the sulfur impurity than the heavy crude oil. 49. The method of claim 48, wherein the lighter oil products comprise about 30% by weight or less of the sulfur impurity than the heavy crude oil. 50. A method for recovering petroleum products from a petroleum-bearing formation, comprising: flowing a nanocatalyst and a reducing agent into a formation comprising a heavy crude oil, wherein the nanocatalyst and the heavy crude oil form a nanocatalyst heavy oil mixture; positioning a steam generator within the formation; generating and releasing steam from the steam generator to heat the nanocatalyst heavy oil mixture within the formation; forming lighter oil products by hydrogenating the heavy crude oil within the nanocatalyst heavy oil mixture; and extracting the lighter oil products from the formation. 51. The method of claim 50, wherein the nanocatalyst comprises a metal selected from the group consisting of iron, nickel, molybdenum, tungsten, titanium, vanadium, chromium, manganese, cobalt, alloys thereof, oxides thereof, sulfides thereof, derivatives thereof, and combinations thereof. 52. The method of claim 51, wherein the nanocatalyst comprises iron and a metal selected from the group consisting of nickel, molybdenum, tungsten, titanium, vanadium, chromium, manganese, cobalt, alloys thereof, oxides thereof, sulfides thereof, derivatives thereof, and combinations thereof. 53. The method of claim 52, wherein the nanocatalyst comprises iron, nickel, and molybdenum. 54. The method of claim 51, wherein the nanocatalyst comprises a nickel compound and a molybdenum compound. 55. The method of claim 51, wherein the nanocatalyst is supported on carbon nanoparticulate. 56. The method of claim 55, wherein the carbon nanoparticulate has a diameter of less than 1 μm. 57. The method of claim 56, wherein the diameter is within a range from about 5 nm to about 500 nm. 58. The method of claim 51, wherein the nanocatalyst is supported on alumina, silica, molecular sieves, ceramic materials, derivatives thereof, or combinations thereof. 59. The method of claim 50, wherein the nanocatalyst heavy oil mixture is heated by the steam to a temperature of less than about 600° F. 60. The method of claim 59, wherein the temperature is within a range from about 250° F. to about 580° F. 61. The method of claim 60, wherein the temperature is within a range from about 400° F. to about 550° F. 62. The method of claim 50, wherein the reducing agent comprises a reagent selected from the group consisting of hydrogen gas, carbon monoxide, synthetic gas, tetralin, decalin, derivatives thereof, and combinations thereof. 63. The method of claim 62, wherein the nanocatalyst and the reducing agent are co-flowed into the formation. 64. The method of claim 63, wherein the reducing agent comprises hydrogen gas. 65. The method of claim 64, wherein the hydrogen gas has a partial pressure of about 100 psi or greater within the formation. 66. The method of claim 50, wherein the steam is generated by combusting oxygen gas and hydrogen gas within the steam generator. 67. The method of claim 66, wherein the oxygen gas and the hydrogen gas are each transferred from outside of the formation, through a borehole, and into the formation. 68. The method of claim 50, wherein the steam is generated by combusting oxygen gas and a hydrocarbon gas within the steam generator. 69. The method of claim 68, wherein the oxygen gas and the hydrocarbon gas are each transferred from outside of the formation, through a borehole, and into the formation. 70. The method of claim 69, wherein the hydrocarbon gas comprises methane. 71. The method of claim 50, further comprising reducing viscosity of the heavy crude oil by exposing the nanocatalyst heavy oil mixture to carbon dioxide. 72. The method of claim 71, wherein the carbon dioxide is transferred from outside of the formation, through a borehole, and into the formation. 73. The method of claim 50, wherein the lighter oil products comprise a lower concentration of a sulfur impurity than the heavy crude oil. 74. The method of claim 73, wherein the lighter oil products comprise about 50% by weight or less of the sulfur impurity than the heavy crude oil. 75. The method of claim 74, wherein the lighter oil products comprise about 30% by weight or less of the sulfur impurity than the heavy crude oil. 76. A method for recovering petroleum products from a petroleum-bearing formation, comprising: flowing a carrier gas through a first vessel containing a first batch of a catalytic material comprising a nanocatalyst within a first vessel; preparing a second batch of the catalytic material within a second vessel; flowing the catalytic material and the carrier gas from the first vessel and into a formation comprising a heavy crude oil, wherein the nanocatalyst and the heavy crude oil form a nanocatalyst heavy oil mixture; exposing the nanocatalyst heavy oil mixture to a reducing agent; positioning a steam generator within the formation; generating and releasing steam from the steam generator to heat the nanocatalyst heavy oil mixture within the formation; forming lighter oil products by hydrogenating the heavy crude oil within the nanocatalyst heavy oil mixture; and extracting the lighter oil products from the formation. 77. The method of claim 76, wherein the carrier gas comprises carbon dioxide. 78. The method of claim 76, wherein preparing the second batch of the catalytic material further comprises combining the nanocatalyst and nanoparticulate within the second vessel. 79. The method of claim 78, wherein the nanocatalyst comprises a metal selected from the group consisting of iron, nickel, molybdenum, tungsten, titanium, vanadium, chromium, manganese, cobalt, alloys thereof, oxides thereof, sulfides thereof, derivatives thereof, and combinations thereof. 80. The method of claim 79, wherein the nanoparticulate comprises carbon, alumina, silica, molecular sieves, ceramic materials, derivatives thereof, or combinations thereof. 81. The method of claim 80, wherein the nanoparticulate has a diameter of less than 1 μm. 82. The method of claim 81, wherein the diameter is within a range from about 5 nm to about 500 nm. 83. A method for recovering petroleum products from a petroleum-bearing formation, comprising: flowing a nanocatalyst and a reducing agent into a formation comprising a heavy crude oil, wherein the nanocatalyst and the heavy crude oil form a nanocatalyst heavy oil mixture; heating the nanocatalyst heavy oil mixture within the formation to a temperature of less than about 600° F.; forming lighter oil products by hydrogenating the heavy crude oil within the nanocatalyst heavy oil mixture; and extracting the lighter oil products from the formation. 84. The method of claim 83, wherein heating the nanocatalyst heavy oil mixture within the formation further comprises flowing heated gas, liquid, or fluid from outside of the formation, through a borehole, and into the formation while exposing the nanocatalyst heavy oil mixture. 85. The method of claim 84, wherein the nanocatalyst heavy oil mixture is exposed to heated water, steam, or combinations thereof. 86. The method of claim 83, wherein the nanocatalyst heavy oil mixture is heated within the formation by an electric heater positioned within the formation. 87. The method of claim 83, wherein heating the nanocatalyst heavy oil mixture within the formation further comprises: positioning a steam generator within the formation; and generating and releasing steam from the steam generator to heat the nanocatalyst heavy oil mixture within the formation. 88. The method of claim 83, wherein the temperature is within a range from about 250° F. to about 580° F. 89. The method of claim 88, wherein the temperature is within a range from about 400° F. to about 550° F.
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