CA2445173A1 - In situ recovery from a tar sands formation - Google Patents

In situ recovery from a tar sands formation Download PDF

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Publication number
CA2445173A1
CA2445173A1 CA002445173A CA2445173A CA2445173A1 CA 2445173 A1 CA2445173 A1 CA 2445173A1 CA 002445173 A CA002445173 A CA 002445173A CA 2445173 A CA2445173 A CA 2445173A CA 2445173 A1 CA2445173 A1 CA 2445173A1
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CA
Canada
Prior art keywords
formation
mixture
section
hydrocarbons
heat
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.)
Granted
Application number
CA002445173A
Other languages
French (fr)
Other versions
CA2445173C (en
Inventor
Steven Dexter Crane
Meliha Deniz Sumnu Dindoruk
John Michael Karanikas
Kevin Albert Maher
Ann Margaret Messier
Eric De Rouffignac
Harold J. Vinegar
Scott Lee Wellington
Etuan Zhang
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Shell Canada Ltd
Original Assignee
Shell Canada Limited
Steven Dexter Crane
Meliha Deniz Sumnu Dindoruk
John Michael Karanikas
Kevin Albert Maher
Ann Margaret Messier
Eric De Rouffignac
Harold J. Vinegar
Scott Lee Wellington
Etuan Zhang
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 Shell Canada Limited, Steven Dexter Crane, Meliha Deniz Sumnu Dindoruk, John Michael Karanikas, Kevin Albert Maher, Ann Margaret Messier, Eric De Rouffignac, Harold J. Vinegar, Scott Lee Wellington, Etuan Zhang filed Critical Shell Canada Limited
Priority to CA2668392A priority Critical patent/CA2668392C/en
Priority to CA2668391A priority patent/CA2668391C/en
Priority to CA2668390A priority patent/CA2668390C/en
Priority to CA2668387A priority patent/CA2668387C/en
Priority to CA2668389A priority patent/CA2668389C/en
Priority to CA2668385A priority patent/CA2668385C/en
Publication of CA2445173A1 publication Critical patent/CA2445173A1/en
Application granted granted Critical
Publication of CA2445173C publication Critical patent/CA2445173C/en
Anticipated expiration legal-status Critical
Expired - Fee Related legal-status Critical Current

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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]
    • 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
    • E21B36/00—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • E21B36/04—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using electrical heaters
    • 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
    • E21B43/14—Obtaining from a multiple-zone well
    • 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
    • E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
    • 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
    • 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
    • E21B43/243—Combustion in situ

Abstract

A method for treating a tar sands formation (32) in situ includes providing heat from one or more heat sources (30) to a portion of the tar sands formation. The heat may be allowed to transfer from the heat source(s) to a selected section of the formation to pyrolyze at least some hydrocarbons within the selected section. A mixture of hydrocarbons of a selected quality may be produced from the selected section by controlling production of the mixture to adjust the time that at least some hydrocarbons are exposed to pyrolysis temperatures in the formation.

Claims (86)

1. A method for treating a hydrocarbon containing formation in situ, comprising:
providing heat from one or more heat sources to at least a portion of the formation;
allowing the heat to transfer from the one or more heat sources to a selected section of the formation such that the heat pyrolyzes at least some hydrocarbons within the selected section; and producing a mixture of hydrocarbons from the selected section; characterised in that the formation is a tar sand formation, that the heat sources comprise heaters and that the method further comprises:
controlling production of the mixture to adjust the time that at least some hydrocarbons are exposed to pyrolysis temperatures in the formation in order to produce hydrocarbons of a selected quality in the mixture.
2. The method of claim 1, further comprising inhibiting production of at least a portion of the mixture of hydrocarbons until at least some hydrocarbons have been pyrolyzed.
3. The method of any one of claims 1-2, wherein the selected quality comprises a selected minimum API
gravity.
4. The method of any one of claims 1-3, wherein the selected quality comprises an API gravity of at least about 20°.
5. The method of any one of claims 1-4, wherein the selected quality comprises a selected maximum weight percentage of heavy hydrocarbons.
6. The method of any one of claims 1-5, wherein the selected quality of the mixture of hydrocarbons comprises a mean carbon number that is less than 12.
7. The method of any one of claims 1-6, further comprising producing a mixture from the selected section through at least one production well.
8. The method of any one of claims 1-7, further comprising sampling a test stream of the produced mixture to determine the selected quality of the produced mixture.
9. The method of any one of claims 1-8, further comprising determining the time that at least some hydrocarbons in the produced mixture are subjected to pyrolysis temperatures using laboratory treatment of formation samples.
10. The method of any one of claims 1-9, further comprising determining the time that at least some hydrocarbons in the produced mixture are subjected to pyrolysis temperatures using a computer simulation of treatment of the formation.
11. The method of any one of claims 1-10, further comprising maintaining a pressure within the selected section such that the pressure is maintained below a lithostatic pressure of the formation.
12. The method of any one of claims 1-11, further comprising maintaining a pressure within the selected section such that the pressure is maintained below a hydrostatic pressure of the formation.
13. The method of any one of claims 1-12, further comprising controlling the selected quality of the mixture of hydrocarbons by controlling the heat provided from at least one of the heaters.
14. The method of any one of claims 1-13, further comprising controlling the selected quality of the mixture of hydrocarbons by controlling pressure at one or more production wells within the formation.
15. The method of any one of claims 1-14, further comprising maintaining a pressure in the formation below 35 bars absolute.
16. The method of any one of claims 1-15, further comprising maintaining an average temperature within the selected section below 375 °C.
17. The method of any one of claims 1-16, further comprising producing the mixture of hydrocarbons when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.
18. The method of any one of claims 1-17, wherein the heat provided from at least one heat source is transferred to at least a portion of the formation substantially by conduction.
19. The method of any one of claims 1-18, wherein one or more of the heaters comprise electrical, combustion, radiofrequency and/or other heaters.
20. The method of any one of claims 1-19, further comprising:
providing heat from a first set of one or more heaters to a first section of the formation such that the heat provided to the first section pyrolyzes at least some hydrocarbons;
providing heat from a second set of one or more heaters to a second section of the formation such that the heat provided to the second section mobilizes at least some hydrocarbons;

inducing at least a portion of the hydrocarbons from the second section to flow into the first section; and producing a mixture of hydrocarbons from the formation, wherein the. produced mixture comprises at least some pyrolyzed hydrocarbons.
21. The method of claim 20, further comprising providing heat to the second section such.that the heat provided to the second section pyrolyzes at least some hydrocarbons.
22. The method of any one of claims 20-21, further comprising:
providing heat from. a third set of one or more heat sources to a third section of the formation such that the heat provided to the third section mobilizes at least some hydrocarbons in the third section; and allowing a portion of the hydrocarbons from the third section to flow into the first section through the second section.
23. The method of claim 22, wherein the third section is substantially adjacent to the second section and/or the second section is substantially adjacent to the first section.
24. The method of claim 22 or 23, further comprising pyrolyzing at least some hydrocarbons in the third section with.the heat provided to the third section.
25. The method of any one of claims 20-24, further comprising producing the mixture of hydrocarbons through at least one production well in or proximate the first section.
26. The method of any one of claims 20-25, further comprising inducing at least a portion of the mobilized hydrocarbons to flow from the second section into the first section.
27. The method of any one of claims 1-19, further, comprising:
providing heat from one or more heaters. to a selected section of the formation such that the heat provided to the selected section pyrolyzes at least some. hydrocarbons in a lower portion of the formation; and producing a mixture of hydrocarbons from an upper portion of the formation, wherein the mixture of hydrocarbons comprises at least some pyrolyzed hydrocarbons, from the lower portion of the formation.
28. The method of claim 27, wherein the upper portion comprises about an upper one-half of the tar sands formation.
29. The method of.any one of claims 27-28, wherein the lower portion comprises about a lower one-half of the tar sands formation.
30. The method of any one of claims 27-29,further comprising producing the mixture of hydrocarbons as a vapour.
31. The method of any one of claims 27-30, wherein the mixture of hydrocarbons comprises an API gravity greater than about l5°.
32. The method of any one of claims 27-31, further comprising inducing at least a portion of the hydrocarbons from the lower portion to flow into the upper portion.
33. The method of any one of claims 1-26, further comprising:
selectively limiting a temperature proximate a selected portion of a heater well to inhibit coke formation at or near the selected portion; and producing a mixture of at least some hydrocarbons through the selected portion of the heater well.
34. The method of claim 33,further comprising generating water in the selected portion to inhibit coke formation at or near the selected portion of the heater well.
35 . The method of any one of claims 33-34, wherein the heater well is placed substantially horizontally within the selected section.
36. The method of any one of claims 33-35, wherein selectively limiting the temperature comprises providing Less heat at the selected portion of the heater well than other portions of the heater well in the selected section.
37. The method of any one of claims 33-36, wherein selectively limiting the temperature comprises maintaining the temperature proximate the selected portion below pyrolysis temperatures.
38. The method of any one of claims 33-37, further comprising producing a mixture from the selected section through at least one production well.
39. The method of any one of claims 33-38, further comprising providing at least some heat to an overburden section of the heater well to maintain the produced hydrocarbons in a vapour phase.
40. The method of any one of claims 1-19, further comprising:
controlling a quality of the produced mixture by varying a location for producing the mixture.
41. The method of claim 40, further comprising producing the mixture of hydrocarbons through,at least one production well in or proximate the selected section.
42. The method of any one. of claims 40-41, wherein varying a production location within a production well comprises varying a location of perforations used to produce the mixture within the production well and/or varying a location of a production well within the formation and/or varying a number of production wells in the formation.
43.-The method of any one of claims 40-41,wherein varying the location for producing the mixture comprises varying a location of a substantially horizontal production well within the formation.
44. The method of any one of claims 40-43, wherein varying the location for producing the mixture comprises varying a distance between a production well and one or more heat sources.
45. The method according to any one of claims 1-19, wherein. the method is used to produce a blending agent from the selected section, wherein at least a portion. of the blending agent is adapted to blend with a second mixture to produce a third mixture with a selected property.
46. The method of claim 45, wherein the second mixture comprises a viscous crude oil having an API gravity below about l5° and the blending agent is adapted to blend with the viscous liquid to produce a third mixture with a lower viscosity than the viscous liquid.
47. The method of any one of claims 45-46, further comprising producing the second mixture from a second section of a tar sands formation and blending the second mixture with the blending agent to produce the third mixture.
48. The.method of claim 47, wherein the selected section and the second section are located in different tar sands formations which are horizontally and/or vertically displaced.
49. The method of claim 40, wherein the selected section and the second section are vertically displaced within a single tar sands formation.
50. The method of any one of claims 45-49, further.
comprising cold producing the second mixture from a second section of.a tar sands formation.
51. The method of any one of claims 45-50, further comprising injecting the blending agent into.a second section of a tar sands formation to produce the third mixture in the tar sands formation.
52. The method of any one of claims 45-51, further comprising injecting the blending agent into a production well in a second section of a tar sands formation to produce the third mixture in the production well.
53. The method of any one of claims 45-52, wherein the third mixture is suitable for transport through a pipeline.
54. The method of any one of claims 45-53, wherein. the second mixture has a high viscosity that inhibits economical transport over more than 100 km via a pipeline but the third mixture has a reduced viscosity that permits economical transport over more than 100 km via a pipeline.
.
55. The method of any one of claims 45-54, wherein the selected property of the third mixture is created by blending the blending agent and liquid such that the third mixture has a selected API gravity, a selected viscosity, a selected density, a selected asphaltene to saturated hydrocarbon ratio, a selected aromatic hydrocarbon to saturated hydrocarbon ratio, and/or a selected impurity level.
56. The method of any one of claims 45-55, wherein the selected property of the third mixture comprises an API
gravity of greater than about 10°.
57. The method of any one of claims 45-56, wherein the selected property of the third mixture comprises a viscosity of less than about 7500 cs.at about 4 °C.
58. The method of any one of claims 45-57, wherein the selected property of the third mixture comprises a density of less than about 1 g/cm3 at about 4 °C.
59. The method of any one of claims 45-58, wherein the selected property of the third mixture comprises an asphaltene to saturated hydrocarbon ratio of less than 1.
60. The method of any one of claims 45-59, wherein the selected property of the third mixture comprises an aromatic hydrocarbon to saturated hydrocarbon ratio of less than 4.
61. The method of any one of claims 45-60, wherein the blending agent comprises at least some pyrolyzed .
hydrocarbons.
62. A blending agent produced by the method of any one of claims 45-61.
63. The blending agent according to claim 62, wherein,the blending agent comprises an API gravity of at least about 15°.
64. A mixture of the blending agent of claim 62 or 63 and a liquid, wherein asphaltenes are substantially stable in the mixture at ambient temperature.
65. A mixture of the blending agent of claim 62 or 63 and a liquid, wherein the mixture comprises equal to or less than about 20% by weight of the blending agent.
66. A pumpable mixture produced by mixing the blending agent of any one of claims 62-63 with a viscous crude oil, wherein the blending agent is produced according to the method of any one of claims 45-6l,and wherein the pumpable .mixture has a selected property such as selected.
API gravity, a selected viscosity, a selected density, and/or a selected impurity.
67. A mixture of hydrocarbons obtainable by the method according to any one of claims 1-61.
68. The mixture of claim 67, wherein the mixture is obtained by the method according to any one of claims 1-61.
69. A method for treating a hydrocarbon containing formation in situ, comprising:
providing heat from one or more heat sources to at least a portion of the formation;
allowing the heat to transfer from the one or more heat sources to a selected section of the formation such that the heat reduces the viscosity of at least some hydrocarbons within the selected section; characterised in that the formation is a tar sand formation, that the heat sources comprise heaters and that the method further comprises:
providing a gas to the selected section of the formation, wherein the gas produces a flow of at least some hydrocarbons within the selected section; and producing a mixture of hydrocarbons from the selected section.
70. The method of claim 69, further comprising increasing a pressure in the selected section with the provided gas.
71. The method of any one of claims 69-70, wherein a spacing between heated sections of one or more heaters is less than about 50 m and greater than about 5 m.
72. The method of any one of claims 69-71, wherein the gas comprises carbon dioxide. and/or nitrogen and/or methane.
73. The method of any one of claims 69-72, wherein the gas comprises steam and/or water, and wherein the water forms steam in the formation.
74. The method of any one of claims 69-73, wherein the gas comprises gases produced from the formation.
75. The method of any one of claims 69-74, further .
comprising allowing heat to transfer to the selected section such that the provided heat pyrolyzes at least some hydrocarbons within the selected section in accordance with the method of any one of claims 1-61.
76. The method of any one of claims 69-74, further comprising controlling the transfer of heat from the one or more heaters and controlling the flow of provided gas such that the flow of hydrocarbons within the selected section is controlled.
77. The method of any one of claims 69-76, further comprising producing the mixture of hydrocarbons through at least one production well in or proximate the selected section.
78. The method of any one of claims 69-77, further comprising providing the gas through at least one injection well in the selected section.
79. The method of any one of claims 69-77, wherein at least one production well and at least one injection well are placed substantially horizontally in the selected section, and wherein at least one heater is placed substantially vertically in the selected section to create a path for flow along a length of the heater between at least one production well and at least one injection well.
80. The method of any one of claims 69-77, wherein at least one production well and at least one injection well are placed substantially vertically in the selected _97_ section, and wherein at least one heater is placed substantially horizontally in the selected section to create a path for flow along a length of the heater between at least one production well and at least one injection well.
81. The method of claim 79 or 80, wherein the heater is turned off when the path for flow along the length of the heat source is created.
82. A method for treating a hydrocarbon containing formation in situ, comprising:
providing heat from a first set of one or more heat sources to a first section of the formation such that the heat provided to the first section pyrolyzes at least some hydrocarbons; characterised in that the formation is a tar sand formation, that the first set of one or more heat sources comprise one or more heaters and that the method further comprises:
providing heat from a second set of one or more heaters to a second section of the formation such that the heat provided to the second section mobilizes at least some hydrocarbons;
inducing at least a portion of the hydrocarbons from the second section to flow into the first section; and producing a mixture of hydrocarbons from the formation, wherein the produced mixture comprises at least some pyrolyzed hydrocarbons.
83. A method for treating a hydrocarbon containing formation in situ, comprising:
providing heat from one or more heat sources to at least a portion of the formation;
allowing the heat to transfer from the one or more heat sources to a selected section of the formation such that the heat pyrolyzes at least some hydrocarbons within the selected section: characterised in that the formation is a tar sands formation and that the method further comprises:
selectively limiting a temperature proximate a selected portion of a heater well to inhibit coke formation at or near the selected portion; and producing a mixture of at least some hydrocarbons through the selected portion of the heater well.
84. A method for treating a hydrocarbon containing formation in situ, comprising:
providing heat from one or more heat sources to at, least a portion of the formation;
allowing the heat to transfer from the one or more heat sources to a selected section of the formation such that the heat pyrolyzes at least some hydrocarbons within the selected section; characterised in that the formation is a tar sand formation that the heat sources comprise heaters and that the method further comprises:
producing a mixture from the selected section; and controlling a quality of the produced mixture by varying a location for producing the mixture.
85. A method for treating a hydrocarbon containing formation in situ, comprising:
providing heat from one or more heat sources to a selected section of the formation such that the heat provided to the selected section pyrolyzes at least some hydrocarbons; characterised in that the formation is a tar sand formation, that the heat sources comprise heaters and that the method further comprises:
producing a blending agent from the selected section, wherein at least a portion of the blending agent is adapted to blend with a liquid to produce a mixture with a selected property.
86. A method for treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heat sources to a selected section of the formation such that the heat provided to the selected section pyrolyzes at least some hydrocarbons in a lower portion of the formation;
characterised in that the formation is a tar sand formation, that the heat sources comprise heaters and that the method further comprises:
producing a mixture of hydrocarbons from an upper portion of the formation, wherein the mixture of hydrocarbons comprises at least some pyrolyzed hydrocarbons from the lower portion of the formation.
CA2445173A 2001-04-24 2002-04-24 In situ recovery from a tar sands formation Expired - Fee Related CA2445173C (en)

Priority Applications (6)

Application Number Priority Date Filing Date Title
CA2668392A CA2668392C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668391A CA2668391C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668390A CA2668390C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668387A CA2668387C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668389A CA2668389C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668385A CA2668385C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation

Applications Claiming Priority (5)

Application Number Priority Date Filing Date Title
US28615601P 2001-04-24 2001-04-24
US60/286,156 2001-04-24
US33705901P 2001-10-24 2001-10-24
US60/337,059 2001-10-24
PCT/EP2002/004549 WO2002086276A2 (en) 2001-04-24 2002-04-24 Method for in situ recovery from a tar sands formation and a blending agent produced by such a method

Related Child Applications (6)

Application Number Title Priority Date Filing Date
CA2668385A Division CA2668385C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668389A Division CA2668389C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668391A Division CA2668391C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668387A Division CA2668387C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668392A Division CA2668392C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668390A Division CA2668390C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation

Publications (2)

Publication Number Publication Date
CA2445173A1 true CA2445173A1 (en) 2002-10-31
CA2445173C CA2445173C (en) 2011-03-15

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Family Applications (7)

Application Number Title Priority Date Filing Date
CA2668390A Expired - Fee Related CA2668390C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2445173A Expired - Fee Related CA2445173C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668389A Expired - Lifetime CA2668389C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668391A Expired - Fee Related CA2668391C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668385A Expired - Fee Related CA2668385C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668392A Expired - Fee Related CA2668392C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668387A Expired - Fee Related CA2668387C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation

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Application Number Title Priority Date Filing Date
CA2668390A Expired - Fee Related CA2668390C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation

Family Applications After (5)

Application Number Title Priority Date Filing Date
CA2668389A Expired - Lifetime CA2668389C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668391A Expired - Fee Related CA2668391C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668385A Expired - Fee Related CA2668385C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668392A Expired - Fee Related CA2668392C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation
CA2668387A Expired - Fee Related CA2668387C (en) 2001-04-24 2002-04-24 In situ recovery from a tar sands formation

Country Status (10)

Country Link
US (1) US7066254B2 (en)
EP (1) EP1381749B1 (en)
CN (1) CN100545415C (en)
AT (1) ATE384852T1 (en)
AU (1) AU2002304692C1 (en)
CA (7) CA2668390C (en)
DE (1) DE60224793T2 (en)
EA (1) EA009350B1 (en)
NZ (1) NZ529140A (en)
WO (1) WO2002086276A2 (en)

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