US4565249A
Expired / Lapsed
US
⏱️ 0.0 years remaining
Heavy oil recovery process using cyclic carbon dioxide steam stimulation
Assignee: Mobil Oil AS
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Filing: 1984-09-20
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Granted: 1986-01-21
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Expires: 2004-09-20
Abstract
Abstract A method for the recovery of viscous oil from subterranean formations including tar sands by the injection of a mixture of carbon dioxide and steam into the formation through an injection well, after which formation fluids are recovered from the well in a cyclic manner, using the well alternately for injection and production. Incremental recovery is optimized by maintaining the ratio of carbon dioxide to steam within the range 200 to 300, preferably 230 to 270 SCF carbon dioxide per barrel of steam (with water equivalent) in the injected mixture.
Inventors
- 👤 Farrokh N. Pebdani
- 👤 Winston R. Shu
Bibliographic Details
Application Number
—
Jurisdiction
US
Data Source
google_patents
Last Synchronized
2026-10-29 20:56
CPC Classifications
E; E21; E21B; E21B43/00; E21B43/16; E21B43/164; E21B43/24
Claims Analysis
Total Claims: 9
Claim 1
Independent Claim
77 words
A method of recovering oil from a subterranean, viscous oil-containing formation penetrated by at least one well in fluid communication with a substantial portion of the formation, comprising: (i) injecting a mixture of carbon dioxide and steam into the formation through the well, the ratio of carbon dioxide to steam being from 200 to 300 SCF carbon dioxide per barrel of steam (cold water equivalent); and (ii) recovering fluids including oil from the formation through the well.
Claim 2
Independent Claim
77 words
A method of recovering oil from a subterranean, viscous oil-containing formation penetrated by at least one well in fluid communication with a substantial portion of the formation, comprising: (i) injecting a mixture of carbon dioxide and steam into the formation through the well, the ratio of carbon dioxide to steam being from 200 to 300 SCF carbon dioxide per barrel of steam (cold water equivalent); and (ii) recovering fluids including oil from the formation through the well.
Claim 3
Dependent Claim
17 words
The method of claim 1 wherein steps (i) and (ii) are repeated for a plurality of cycles.
Claim 4
Dependent Claim
21 words
The method of claim 1 wherein the temperature of the steam is in the range of 400° F. to 650° F.
Claim 5
Dependent Claim
52 words
The method of claim 1 wherein the amount of steam injected with the cabon dioxide during step (i) is about 180 barrels of steam (cold water equivalent) per foot of net pay and the injection rate is about 6 barrels of steam (cold water equivalent) per day per foot of net pay.
Claim 6
Dependent Claim
17 words
The method of claim 1 wherein the steam quality is in the range of 50% to 85%.
Claim 7
Dependent Claim
25 words
The method of claim 1 further including the steps of shutting-in the well after step (i) to allow the formation to undergo a soak period.
Claim 8
Dependent Claim
29 words
The method of claim 1 in which the ratio of carbon dioxide to steam is from 230 to 270 SCF carbon dioxide per barrel of steam (cold water equivalent).
Claim 9
Dependent Claim
27 words
The method of claim 1 in which the ratio of cabon dioxide to steam is about 250 SCF carbon dioxide per barrel of steam (cold water equivalent).
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USPTO Annuity & Maintenance Windows
| Annuity Stage | Window Opens | Payment Deadline | Surcharge Period Until | Estimated Fee | Status |
|---|---|---|---|---|---|
| 3.5 Years (Year 4) | 1989-01-20 | 1989-07-22 | 1990-01-21 | $2000.00 | Window Closed / Lapsed |
| 7.5 Years (Year 8) | 1993-01-20 | 1993-07-22 | 1994-01-21 | $3760.00 | Window Closed / Lapsed |
| 11.5 Years (Year 12) | 1997-01-20 | 1997-07-22 | 1998-01-21 | $7700.00 | Window Closed / Lapsed |