US20040050547A1 - Downhole upgrading of oils - Google Patents
Downhole upgrading of oils Download PDFInfo
- Publication number
- US20040050547A1 US20040050547A1 US10/244,320 US24432002A US2004050547A1 US 20040050547 A1 US20040050547 A1 US 20040050547A1 US 24432002 A US24432002 A US 24432002A US 2004050547 A1 US2004050547 A1 US 2004050547A1
- Authority
- US
- United States
- Prior art keywords
- oil
- oxygen
- well
- reservoir
- production well
- 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.)
- Abandoned
Links
- 239000003921 oil Substances 0.000 title claims abstract description 66
- 229910052760 oxygen Inorganic materials 0.000 claims abstract description 34
- 239000001301 oxygen Substances 0.000 claims abstract description 34
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims abstract description 33
- 238000004519 manufacturing process Methods 0.000 claims abstract description 26
- 238000002347 injection Methods 0.000 claims abstract description 24
- 239000007924 injection Substances 0.000 claims abstract description 24
- 238000005336 cracking Methods 0.000 claims abstract description 8
- 238000000034 method Methods 0.000 claims description 36
- 230000008569 process Effects 0.000 claims description 24
- 238000002485 combustion reaction Methods 0.000 claims description 14
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 9
- 238000011065 in-situ storage Methods 0.000 claims description 7
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 5
- 239000001569 carbon dioxide Substances 0.000 claims description 4
- 239000000295 fuel oil Substances 0.000 claims description 4
- MYMOFIZGZYHOMD-UHFFFAOYSA-N Dioxygen Chemical compound O=O MYMOFIZGZYHOMD-UHFFFAOYSA-N 0.000 claims description 2
- 239000003054 catalyst Substances 0.000 claims description 2
- 238000000926 separation method Methods 0.000 claims description 2
- 230000004907 flux Effects 0.000 abstract description 4
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 12
- 239000007789 gas Substances 0.000 description 11
- 229910052757 nitrogen Inorganic materials 0.000 description 6
- 238000010796 Steam-assisted gravity drainage Methods 0.000 description 4
- 238000006073 displacement reaction Methods 0.000 description 3
- XQCFHQBGMWUEMY-ZPUQHVIOSA-N Nitrovin Chemical compound C=1C=C([N+]([O-])=O)OC=1\C=C\C(=NNC(=N)N)\C=C\C1=CC=C([N+]([O-])=O)O1 XQCFHQBGMWUEMY-ZPUQHVIOSA-N 0.000 description 2
- CJPQIRJHIZUAQP-MRXNPFEDSA-N benalaxyl-M Chemical compound CC=1C=CC=C(C)C=1N([C@H](C)C(=O)OC)C(=O)CC1=CC=CC=C1 CJPQIRJHIZUAQP-MRXNPFEDSA-N 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 239000000571 coke Substances 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000003575 carbonaceous material Substances 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 229910001882 dioxygen Inorganic materials 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 230000020169 heat generation Effects 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 230000004941 influx Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 229910052751 metal Inorganic materials 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 150000002739 metals Chemical class 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 150000002926 oxygen Chemical class 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 238000000746 purification Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 239000002904 solvent Substances 0.000 description 1
- 229910001220 stainless steel Inorganic materials 0.000 description 1
- 239000010935 stainless steel Substances 0.000 description 1
- 229910052717 sulfur Inorganic materials 0.000 description 1
- 239000011593 sulfur Substances 0.000 description 1
- 230000008961 swelling Effects 0.000 description 1
- 238000011144 upstream manufacturing 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
- E21B43/243—Combustion in situ
Definitions
- the present invention relates to the injection of oxygen or oxygen-enriched air into an oil reservoir causing in-situ combustion to occur and the oil to crack into lighter fractions.
- ISC in-situ combustion
- HOAI heavy oil air injection
- vertical wells are used for injection of air and typically water for the production of oil.
- the distance between the wells is often substantial and oil and water vaporized by the combustion and upgrading process condense in the cooler parts of the reservoir, travel through the heavy oil and are produced via well techniques. Due to the highly viscous oils through which these lighter fluids must travel, it may be difficult to maintain production and pressure may build on the injection side. This may be one reason for failure of field applications of such technology in the past.
- a short distance process may be utilized in which a vertical or horizontal injection well and a horizontal producer well are used so that displacement of oil can be achieved along the horizontal producer well.
- a combustion front propagates through the reservoir above the horizontal well allowing good communication of the upgraded oil and the production well.
- One example of such a process is the Toe to Heel Air Injection (THAI) process.
- THAI Toe to Heel Air Injection
- a catalyst may be placed in the producer well to obtain further upgrading of the oil, as in the CAPRI process.
- the Combustion Override Split-production Horizontal well (COSH) process also uses air injected into the reservoir to generate steam and heat in-situ.
- a well arrangement is used to segregate and control fluid flows and thereby reduce early oxygen breakthrough as well as sanding and gas locking of downhole pumps.
- the well arrangement makes use of an air injection well, gas producer well which removes excess nitrogen and other gases from near the top of the pay zone, and horizontal well to recover oil from a lower portion of the pay zone.
- the COSH process has an advantage over the THAI and CAPRI processes in that problems which arise from the handling of nitrogen and other gases are reduced.
- SAGD Steam Assisted Gravity Drainage
- VAPEX Vapor Extraction
- the present invention provides for a method for cracking oil in an underground oil reservoir comprising injecting oxygen into the oil reservoir and igniting the oil therein.
- the combustion associated with the high influx of oxygen will generate high temperatures which will cause the oil to crack into lighter fractions to form coke or carbonaceous solids from the heaviest compounds in the oil such as asphaltenes.
- the present invention also provides for injecting oxygen into the oil reservoir such that in-situ combustion can take place for recovering the oil through one or more production wells.
- the present invention provides for an in-situ combustion process for recovering oil from an underground oil containing reservoir.
- the process comprises injecting oxygen into the oil reservoir. This oxygen will react to combust the oil which causes heat generation. The resulting high temperatures will cause the oil to crack into lighter fractions.
- the invention is most applicable for heavy oil or tar sands. By injecting oxygen and igniting the oil in the presence of the oxygen, high temperatures greater than 400° C. and preferably greater than 500° C. cause the oil to crack to form lighter more valuable products, as well as coke or carbonaceous solids. In addition, higher temperatures are desirable to facilitate the formation of CO 2 . Less desirable oxygen containing hydrocarbons may be formed at lower temperatures.
- oxygen can mean pure 100% oxygen gas, but it can also include oxygen-enriched air which contains oxygen in an amount greater than 25%. Purification of the oxygen allows for a significantly higher flux of oxygen to be placed into the well due to the reduction of associated nitrogen which would be present in air. This aids in increasing the temperature which increases the cracking severity but also provides for reducing the need to handle nitrogen in the gases at the production well.
- a horizontal producer well and vertical injection well is employed.
- the horizontal producer well will result in a short distance displacement process whereby oil and water vaporized by the intense heat of the oil combustion front can travel freely to the horizontal producer well. This will allow the large flux of oxygen into the reservoir to continue unhampered by upstream blockages. Injectivity of oxygen-containing gas is increased by the combustion of carbonaceous materials near the injection well.
- two sets of horizontal wells may be employed whereby oxygen is injected in one set of horizontal wells and oil is produced from a lower perpendicular set of horizontal wells.
- the oxygen when injected into the reservoir, may be ignited by an electronic device or other form of heat, such as steam, which will increase local temperature in the reservoir
- Water may also be injected with the oxygen once the combustion zone has been established.
- the steam generated in this manner is an efficient means to transfer heat to the oil.
- the cracked oils will be of higher quality in that they are relatively light, virtually free of metals and have a lower sulfur content than the untreated oils.
- the temperatures greater than 400° C. by which the oils are cracked will also improve carbon dioxide production.
- the carbon dioxide is known to reduce viscosity and interfacial tension in the oil as well as to cause swelling of the oil in order to enhance production.
- the use of oxygen necessarily means that less nitrogen or no nitrogen is present in the reservoir such that a much higher flux of oxygen is provided and consequently higher temperatures and higher concentrations of carbon dioxide are present.
- One means of obtaining the oxygen employed in the present invention is from an air separation plant which can be on-site or very close to the actual production wells.
- the well arrangement having a first vertical gas injection well located near the top of the oil bearing portion of the reservoir and a horizontal oil production well located near the bottom of the reservoir. The oxygen would be injected into the first well, combusted and drive the cracked oils into the horizontal oil production well where the oil can be recovered by conventional means.
- several horizontal gas injection wells running substantially parallel to each other are located near the top of the oil bearing portion of the reservoir and several oil producing wells also horizontal and substantially parallel to each other are situated perpendicular to the gas injection wells.
- the injection and production wells may be formed of any material that is commonly employed in the oil production industry.
- One example would be a perforated stainless steel tubing of dimensions sufficient to deliver oil from the reservoir.
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)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
Oils present in oil reservoirs can be upgraded by high temperature cracking through the injection of oxygen into the reservoir and combusting the oils to generate heat. By employing injection wells and production wells, the oxygen may be placed into the reservoir increasing the flux of oxygen present as well as the temperature and cracking severity needed to produce upgraded oil.
Description
- The present invention relates to the injection of oxygen or oxygen-enriched air into an oil reservoir causing in-situ combustion to occur and the oil to crack into lighter fractions.
- In conventional in-situ combustion (ISC) processes, also called fire flooding or heavy oil air injection (HOAI), vertical wells are used for injection of air and typically water for the production of oil. The distance between the wells is often substantial and oil and water vaporized by the combustion and upgrading process condense in the cooler parts of the reservoir, travel through the heavy oil and are produced via well techniques. Due to the highly viscous oils through which these lighter fluids must travel, it may be difficult to maintain production and pressure may build on the injection side. This may be one reason for failure of field applications of such technology in the past. A short distance process may be utilized in which a vertical or horizontal injection well and a horizontal producer well are used so that displacement of oil can be achieved along the horizontal producer well. A combustion front propagates through the reservoir above the horizontal well allowing good communication of the upgraded oil and the production well. One example of such a process is the Toe to Heel Air Injection (THAI) process. A catalyst may be placed in the producer well to obtain further upgrading of the oil, as in the CAPRI process.
- The Combustion Override Split-production Horizontal well (COSH) process also uses air injected into the reservoir to generate steam and heat in-situ. A well arrangement is used to segregate and control fluid flows and thereby reduce early oxygen breakthrough as well as sanding and gas locking of downhole pumps. The well arrangement makes use of an air injection well, gas producer well which removes excess nitrogen and other gases from near the top of the pay zone, and horizontal well to recover oil from a lower portion of the pay zone. The COSH process has an advantage over the THAI and CAPRI processes in that problems which arise from the handling of nitrogen and other gases are reduced.
- Other examples of short distance displacement processes include Steam Assisted Gravity Drainage (SAGD) and Vapor Extraction (VAPEX). In the SAGD process, steam enters through a horizontal injection well and travels a relatively short distance to a horizontal production well. The heating of heavy viscous oils between these wells allows the oils to flow to the production well. The VAPEX process is similar to SAGD but hydrocarbon vapor is used instead of steam. Asphaltene precipitation is caused by the mixing of solvent and oil and provides for an in-situ upgrading of the oil.
- The present invention provides for a method for cracking oil in an underground oil reservoir comprising injecting oxygen into the oil reservoir and igniting the oil therein. The combustion associated with the high influx of oxygen will generate high temperatures which will cause the oil to crack into lighter fractions to form coke or carbonaceous solids from the heaviest compounds in the oil such as asphaltenes.
- The present invention also provides for injecting oxygen into the oil reservoir such that in-situ combustion can take place for recovering the oil through one or more production wells.
- The present invention provides for an in-situ combustion process for recovering oil from an underground oil containing reservoir. The process comprises injecting oxygen into the oil reservoir. This oxygen will react to combust the oil which causes heat generation. The resulting high temperatures will cause the oil to crack into lighter fractions. The invention is most applicable for heavy oil or tar sands. By injecting oxygen and igniting the oil in the presence of the oxygen, high temperatures greater than 400° C. and preferably greater than 500° C. cause the oil to crack to form lighter more valuable products, as well as coke or carbonaceous solids. In addition, higher temperatures are desirable to facilitate the formation of CO2. Less desirable oxygen containing hydrocarbons may be formed at lower temperatures.
- For purposes of the present invention, oxygen can mean pure 100% oxygen gas, but it can also include oxygen-enriched air which contains oxygen in an amount greater than 25%. Purification of the oxygen allows for a significantly higher flux of oxygen to be placed into the well due to the reduction of associated nitrogen which would be present in air. This aids in increasing the temperature which increases the cracking severity but also provides for reducing the need to handle nitrogen in the gases at the production well.
- In one embodiment of the present invention, a horizontal producer well and vertical injection well is employed. The horizontal producer well will result in a short distance displacement process whereby oil and water vaporized by the intense heat of the oil combustion front can travel freely to the horizontal producer well. This will allow the large flux of oxygen into the reservoir to continue unhampered by upstream blockages. Injectivity of oxygen-containing gas is increased by the combustion of carbonaceous materials near the injection well. In a second embodiment, two sets of horizontal wells may be employed whereby oxygen is injected in one set of horizontal wells and oil is produced from a lower perpendicular set of horizontal wells. The oxygen, when injected into the reservoir, may be ignited by an electronic device or other form of heat, such as steam, which will increase local temperature in the reservoir
- Water may also be injected with the oxygen once the combustion zone has been established. The steam generated in this manner is an efficient means to transfer heat to the oil. The cracked oils will be of higher quality in that they are relatively light, virtually free of metals and have a lower sulfur content than the untreated oils. The temperatures greater than 400° C. by which the oils are cracked will also improve carbon dioxide production. The carbon dioxide is known to reduce viscosity and interfacial tension in the oil as well as to cause swelling of the oil in order to enhance production. The use of oxygen necessarily means that less nitrogen or no nitrogen is present in the reservoir such that a much higher flux of oxygen is provided and consequently higher temperatures and higher concentrations of carbon dioxide are present.
- One means of obtaining the oxygen employed in the present invention is from an air separation plant which can be on-site or very close to the actual production wells. In preferred embodiments of the present invention, the well arrangement having a first vertical gas injection well located near the top of the oil bearing portion of the reservoir and a horizontal oil production well located near the bottom of the reservoir. The oxygen would be injected into the first well, combusted and drive the cracked oils into the horizontal oil production well where the oil can be recovered by conventional means. In another preferred embodiment, several horizontal gas injection wells running substantially parallel to each other are located near the top of the oil bearing portion of the reservoir and several oil producing wells also horizontal and substantially parallel to each other are situated perpendicular to the gas injection wells. This provides additional advantages in that the gas injection wells could be used one at a time to upgrade the reservoir oils in the vicinity of that particular gas injection well. The injection and production wells may be formed of any material that is commonly employed in the oil production industry. One example would be a perforated stainless steel tubing of dimensions sufficient to deliver oil from the reservoir.
- While this invention has been described with respect to particular embodiments thereof, it is apparent that numerous other forms and modifications of the invention will be obvious to those skilled in the art. The appended claims of this invention generally should be construed to cover all such obvious forms and modifications which are within the true spirit and scope of the present invention.
Claims (21)
1. A method for cracking oil in an oil reservoir comprising injecting oxygen into said oil reservoir and igniting said oil.
2. The method as claimed in claim 1 further comprising a production well.
3. The method as claimed in claim 1 wherein said cracked oil is recovered through said production well.
4. The method as claimed in claim 1 wherein said oil comprises heavy oil and tar sands.
5. The method as claimed in claim 1 wherein said cracking is performed at a temperature greater than 400° C.
6. The method as claimed in claim 1 wherein said cracking is performed at a temperature greater than 500° C.
7. The method as claimed in claim 1 wherein said oxygen is pure oxygen or oxygen-enriched air.
8. The method as claimed in claim 7 wherein said oxygen or oxygen-enriched air is produced by an air separation facility.
9. The method as claimed in claim 1 wherein ignition is provided by an electronic device or by steam heat.
10. The method as claimed in claim 1 further comprising injecting water into said oil reservoir.
11. An in-situ combustion process for recovering oil from an underground oil containing reservoir comprising the steps of:
injecting oxygen into said reservoir through an injection well,
combusting and cracking said oil;
producing cracked oil, and
recovering said cracked oil through a production well.
12. The process as claimed in claim 11 wherein said injection well is vertical and said production well is horizontal.
13. The process as claimed in claim 11 wherein said injection well and said production well are horizontal.
14. The process as claimed in claim 11 wherein said production well and said injection well are perpendicular to each other.
15. The process as claimed in claim 11 wherein there are a plurality of injection wells.
16. The process as claimed in claim 11 wherein there are a plurality of production wells.
17. The process as claimed in claim 11 wherein said combustion takes place at temperatures greater than 400° C.
18. The process as claimed in claim 11 wherein said combustion takes place at temperatures greater than 400° C.
19. The process as claimed in claim 11 further comprising recovering carbon dioxide from said production well.
20. The process as claimed in claim 11 wherein said injection well is located near the top of said oil bearing reservoir and said production well is located near the bottom of said oil bearing reservoir.
21. The process as claimed in claim 11 wherein a catalyst is present in said production well.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/244,320 US20040050547A1 (en) | 2002-09-16 | 2002-09-16 | Downhole upgrading of oils |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/244,320 US20040050547A1 (en) | 2002-09-16 | 2002-09-16 | Downhole upgrading of oils |
Publications (1)
Publication Number | Publication Date |
---|---|
US20040050547A1 true US20040050547A1 (en) | 2004-03-18 |
Family
ID=31991885
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US10/244,320 Abandoned US20040050547A1 (en) | 2002-09-16 | 2002-09-16 | Downhole upgrading of oils |
Country Status (1)
Country | Link |
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US (1) | US20040050547A1 (en) |
Cited By (10)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20060042794A1 (en) * | 2004-09-01 | 2006-03-02 | Pfefferle William C | Method for high temperature steam |
US20070187094A1 (en) * | 2006-02-15 | 2007-08-16 | Pfefferle William C | Method for CAGD recovery of heavy oil |
US20070187093A1 (en) * | 2006-02-15 | 2007-08-16 | Pfefferle William C | Method for recovery of stranded oil |
US20090044940A1 (en) * | 2006-02-15 | 2009-02-19 | Pfefferle William C | Method for CAGD recovery of heavy oil |
US20090188667A1 (en) * | 2008-01-30 | 2009-07-30 | Alberta Research Council Inc. | System and method for the recovery of hydrocarbons by in-situ combustion |
US7770643B2 (en) | 2006-10-10 | 2010-08-10 | Halliburton Energy Services, Inc. | Hydrocarbon recovery using fluids |
US7809538B2 (en) | 2006-01-13 | 2010-10-05 | Halliburton Energy Services, Inc. | Real time monitoring and control of thermal recovery operations for heavy oil reservoirs |
CN101864936A (en) * | 2010-03-23 | 2010-10-20 | 邓惠荣 | Authigenic carbon dioxide oil displacement recovery ratio technology in oil layer |
US7832482B2 (en) | 2006-10-10 | 2010-11-16 | Halliburton Energy Services, Inc. | Producing resources using steam injection |
CN106567698A (en) * | 2016-11-07 | 2017-04-19 | 中国石油大学(北京) | Method for increasing oil recovery rate through self-generation carbon dioxide system after polymer flooding |
Citations (7)
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US4202169A (en) * | 1977-04-28 | 1980-05-13 | Gulf Research & Development Company | System for combustion of gases of low heating value |
US4252191A (en) * | 1976-04-10 | 1981-02-24 | Deutsche Texaco Aktiengesellschaft | Method of recovering petroleum and bitumen from subterranean reservoirs |
US4598770A (en) * | 1984-10-25 | 1986-07-08 | Mobil Oil Corporation | Thermal recovery method for viscous oil |
US4651826A (en) * | 1985-01-17 | 1987-03-24 | Mobil Oil Corporation | Oil recovery method |
US4691771A (en) * | 1984-09-25 | 1987-09-08 | Worldenergy Systems, Inc. | Recovery of oil by in-situ combustion followed by in-situ hydrogenation |
US4706751A (en) * | 1986-01-31 | 1987-11-17 | S-Cal Research Corp. | Heavy oil recovery process |
US6412557B1 (en) * | 1997-12-11 | 2002-07-02 | Alberta Research Council Inc. | Oilfield in situ hydrocarbon upgrading process |
-
2002
- 2002-09-16 US US10/244,320 patent/US20040050547A1/en not_active Abandoned
Patent Citations (7)
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US4252191A (en) * | 1976-04-10 | 1981-02-24 | Deutsche Texaco Aktiengesellschaft | Method of recovering petroleum and bitumen from subterranean reservoirs |
US4202169A (en) * | 1977-04-28 | 1980-05-13 | Gulf Research & Development Company | System for combustion of gases of low heating value |
US4691771A (en) * | 1984-09-25 | 1987-09-08 | Worldenergy Systems, Inc. | Recovery of oil by in-situ combustion followed by in-situ hydrogenation |
US4598770A (en) * | 1984-10-25 | 1986-07-08 | Mobil Oil Corporation | Thermal recovery method for viscous oil |
US4651826A (en) * | 1985-01-17 | 1987-03-24 | Mobil Oil Corporation | Oil recovery method |
US4706751A (en) * | 1986-01-31 | 1987-11-17 | S-Cal Research Corp. | Heavy oil recovery process |
US6412557B1 (en) * | 1997-12-11 | 2002-07-02 | Alberta Research Council Inc. | Oilfield in situ hydrocarbon upgrading process |
Cited By (13)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20060042794A1 (en) * | 2004-09-01 | 2006-03-02 | Pfefferle William C | Method for high temperature steam |
US7809538B2 (en) | 2006-01-13 | 2010-10-05 | Halliburton Energy Services, Inc. | Real time monitoring and control of thermal recovery operations for heavy oil reservoirs |
WO2008060311A2 (en) * | 2006-02-15 | 2008-05-22 | Pfefferte, William, C. | Method for cagd recovery of heavy oil |
US20070187093A1 (en) * | 2006-02-15 | 2007-08-16 | Pfefferle William C | Method for recovery of stranded oil |
WO2008060311A3 (en) * | 2006-02-15 | 2008-11-27 | Pfefferte William C | Method for cagd recovery of heavy oil |
US20090044940A1 (en) * | 2006-02-15 | 2009-02-19 | Pfefferle William C | Method for CAGD recovery of heavy oil |
US20070187094A1 (en) * | 2006-02-15 | 2007-08-16 | Pfefferle William C | Method for CAGD recovery of heavy oil |
US7770643B2 (en) | 2006-10-10 | 2010-08-10 | Halliburton Energy Services, Inc. | Hydrocarbon recovery using fluids |
US7832482B2 (en) | 2006-10-10 | 2010-11-16 | Halliburton Energy Services, Inc. | Producing resources using steam injection |
US20090188667A1 (en) * | 2008-01-30 | 2009-07-30 | Alberta Research Council Inc. | System and method for the recovery of hydrocarbons by in-situ combustion |
US7740062B2 (en) | 2008-01-30 | 2010-06-22 | Alberta Research Council Inc. | System and method for the recovery of hydrocarbons by in-situ combustion |
CN101864936A (en) * | 2010-03-23 | 2010-10-20 | 邓惠荣 | Authigenic carbon dioxide oil displacement recovery ratio technology in oil layer |
CN106567698A (en) * | 2016-11-07 | 2017-04-19 | 中国石油大学(北京) | Method for increasing oil recovery rate through self-generation carbon dioxide system after polymer flooding |
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