CA2108723A1 - In-situ bitumen recovery from oil sands - Google Patents
In-situ bitumen recovery from oil sandsInfo
- Publication number
- CA2108723A1 CA2108723A1 CA002108723A CA2108723A CA2108723A1 CA 2108723 A1 CA2108723 A1 CA 2108723A1 CA 002108723 A CA002108723 A CA 002108723A CA 2108723 A CA2108723 A CA 2108723A CA 2108723 A1 CA2108723 A1 CA 2108723A1
- Authority
- CA
- Canada
- Prior art keywords
- hydrocarbon
- aquifer
- deposit
- well
- horizontal
- 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
- 239000010426 asphalt Substances 0.000 title claims abstract description 34
- 238000011084 recovery Methods 0.000 title claims abstract description 16
- 238000011065 in-situ storage Methods 0.000 title description 3
- 238000004519 manufacturing process Methods 0.000 claims abstract description 18
- 238000000034 method Methods 0.000 claims description 33
- 238000005086 pumping Methods 0.000 claims description 5
- 238000005553 drilling Methods 0.000 claims description 4
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 3
- 229930195733 hydrocarbon Natural products 0.000 claims 54
- 150000002430 hydrocarbons Chemical class 0.000 claims 54
- 239000004215 Carbon black (E152) Substances 0.000 claims 40
- 239000002904 solvent Substances 0.000 claims 17
- 238000002347 injection Methods 0.000 claims 11
- 239000007924 injection Substances 0.000 claims 11
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 claims 4
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 claims 2
- 239000001273 butane Substances 0.000 claims 2
- 239000003085 diluting agent Substances 0.000 claims 2
- 239000012530 fluid Substances 0.000 claims 2
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 claims 2
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 claims 2
- 239000001294 propane Substances 0.000 claims 2
- 229930195734 saturated hydrocarbon Natural products 0.000 claims 2
- 238000004891 communication Methods 0.000 claims 1
- 239000000203 mixture Substances 0.000 claims 1
- 230000015572 biosynthetic process Effects 0.000 abstract description 25
- 239000000839 emulsion Substances 0.000 abstract description 15
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 abstract description 12
- 230000005484 gravity Effects 0.000 abstract description 5
- 238000005755 formation reaction Methods 0.000 abstract 4
- 239000007864 aqueous solution Substances 0.000 abstract 1
- 238000010438 heat treatment Methods 0.000 abstract 1
- 239000003027 oil sand Substances 0.000 abstract 1
- 239000003513 alkali Substances 0.000 description 14
- 235000019738 Limestone Nutrition 0.000 description 3
- AXCZMVOFGPJBDE-UHFFFAOYSA-L calcium dihydroxide Chemical compound [OH-].[OH-].[Ca+2] AXCZMVOFGPJBDE-UHFFFAOYSA-L 0.000 description 3
- 239000000920 calcium hydroxide Substances 0.000 description 3
- 229910001861 calcium hydroxide Inorganic materials 0.000 description 3
- 239000006028 limestone Substances 0.000 description 3
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 description 2
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 description 2
- 238000010793 Steam injection (oil industry) Methods 0.000 description 2
- 229910001424 calcium ion Inorganic materials 0.000 description 2
- 238000010790 dilution Methods 0.000 description 2
- 239000012895 dilution Substances 0.000 description 2
- 230000037361 pathway Effects 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 239000012670 alkaline solution Substances 0.000 description 1
- 238000005119 centrifugation Methods 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 239000013256 coordination polymer Substances 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 230000001804 emulsifying effect Effects 0.000 description 1
- 238000005188 flotation Methods 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 229910000029 sodium carbonate Inorganic materials 0.000 description 1
- 239000000126 substance Substances 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
- E21B43/166—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
-
- 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
- E21B43/30—Specific pattern of wells, e.g. optimizing the spacing of wells
- E21B43/305—Specific pattern of wells, e.g. optimizing the spacing of wells comprising at least one inclined or horizontal well
Abstract
ABSTRACT OF THE DISCLOSURE
Bitumen is recovered from subterranean oil sand formations by forming a generally horizontal production well or gallery in the formation and causing bitumen to flow by gravity from the formation into the production well, generally by heating bitumen in the formation using steam. Bitumen in the production well is emulsified using a dilute aqueous solution of sodium hydroxide and the emulsion is transported to the surface or to another remote location for recovery of bitumen from the emulsion at the remote location.
Bitumen is recovered from subterranean oil sand formations by forming a generally horizontal production well or gallery in the formation and causing bitumen to flow by gravity from the formation into the production well, generally by heating bitumen in the formation using steam. Bitumen in the production well is emulsified using a dilute aqueous solution of sodium hydroxide and the emulsion is transported to the surface or to another remote location for recovery of bitumen from the emulsion at the remote location.
Description
` 2~8723 IN-SITU BITUMEN RECOVERY FROM OIL SANDS
The present invention relates to the recovery of bitumen from oil sands by an in-sltu procedure.
One procedure which has been proposed for the recovery of bitumen from subterranean oil sands deposits is by employing dilute alkali, such as a 0.1 wt% sodium hydroxide solution, to emulsify and remove bitumen from the formation, with the resulting emulslon being broken at the surface for recovery of the bitumen.
One problem that can be encountered with such procedure is channelling between the injector and producer wells. After an initial production of bitumen, a pathway of clean sand is produced between the wells.
As more alkali is pumped into the formation, it takes the path of least resistance and continues to flow through the bitumen-depleted pathway and out of the producer well. Accordingly, there is an initial production of rich bitumen-in-oil emulsion that becomes progressively thinner as pumping proceeds.
In accordance with the present invention, we provide an improved procedure for the in-situ recovery of bitumen from oil sands deposits by a horizontal gallery provided in an oil sands formation arrangement in which dilute aqueous alkali is pumped through the gallery to emulsify bitumen therefrom and in which some means is provided to cause bitumen to flow and drain from the formation into the gallery, such as heat from steam pumped into an upper gallery or otherwise into the formation above the gallery. As bitumen flows by gravity into the gallery, it is emulsified by the alkali and then is pumped to the surface for recovery of the bitumen.
The horizontal gallery or well from which the bitumen is recovered may be provided in any convenient manner in the formation, such as by suitable drilling procedures using conventional techniques or hydraulic jetting techniques. Such horizontal gallery may have any desired length and may be substantially vertically 2~723 aligned with an upper gallery or well for introduction of steam. Steam may be pumped into the upper well through the drill line used to form the gallery. Alternatively, steam may be introduced by a plurality of steam injection wells drilled vertically down from the top of the formation.
The bitumen flows through the formation under the influence of the heat introduced to the formation by the steam to the lower gallery wherein it is emulsified with the dilute alkali. Such lower gallery may be a Elow through one, whereby dilute alkali flows through the gallery and the upwardly to the surface, or may be blind ended, in which case dilute alkali can be introduced through an insert pipe extending along the gallery and emulsion is recovered through the annular gap.
perforated outer pipe may be employed or omitted, as desired. A "mud motor" used in the drilling operation may be left at the end of the drill steam during production from the formation.
The emulsion so formed in the lower gallery has a low viscosity and can be readily pumped to the surface, thereby reducing pumping costs. The concentration of bitumen in the emulsion may be controlled by the pumping rate of dilute alkali through the lower gallery emulsion formation may be effected at temperature up to 100C or higher. Heat 109s from the emulsion would not significantly increase the viscosity of the emulsion during pumping since the emulsion has the characteristics of water. The use of dilute alkali minimizes well corrosion.
Further processing of the emulsion is required at the surface to break the emulsion, for example by dilution and/or addition of calcium hydroxide. Bitumen recovery then may be made by flotation or gravity separation, depending on the density of the bitumen.
7 2 ~
Clean up of bitumen, for example, by dilution and centrifugation, may be facilitated by high pH, as descrlbed in our CP 1,243,468. Further incremental addition of calcium hydroxide flocculates any residual mineral materlal and, after removal of the flocculated materials by setting or any suitable mechanical means, provides a clean sodium hydroxide solution for recycle to the well.
Quantities of sodium carbonate, generally 0 to 500 ppm, may be added to the recycle stream to remove any excess free calcium ion remaining in the recovered alkaline solution and to remove any free calcium ion that might be present in the connate water.
The procedure of formation of emulsion from bitumen, transportation to another location, in this case the surface, and processing of the bitumen is somewhat analogous to the procedure described in our Canadian Patent No. 1,137,005. The process conditions described therein for emulsion formation and subsequent bitumen recovery may be employed in the present invention.
The procedure is characterized by a low chemical cost for the calcium hydroxide used in emulsion breaking and clean up and for make up quantities of sodium hydroxide.
The invention is described further, by way of illustration, with reference to the accompanying drawings, in which:
Figure 1 illustrates the method of the present invention with two alternative manners of introduction of steam being illustrated; and Figure 2 illustrates a alternative configuration for the producing well gallery.
Referring to the drawings, a horizontal producing well or gallery 10 is drilled into a lower region of an oil sands formation 12. Such producing well or gallery 10 may comprise an outer perforated casing 14 and an 21 ~8 72~3 inner feed plpe 16. Alternatively, the outer perforated casing 14 may be omitted.
Dilute alkali flows from the surface 18 through the drlll line 20, whlch may extend through overburden 21 from the surface 18 or from galleries formed in limestone 22 underlying the oil sands formation 12. Such dilute alkali flows through the inner pipe 16 in the horizontal gallery or well 14 and exits adjacent the blind end of the gallery and then flows countercurrently in the outer annulus 24, emulsifying bitumen draining into the gallery 10 .
Bitumen may be caused to flow from the formation 12 by gravity into the lower gallery by any suitable means.
Most conveniently, steam is used in this regard, which may be introduced to the upper region cf the oil sands formation 12 above the lower gallery or well 10. In one alternative, a second gallery or well 26 is provided in the formation 12 aligned vertically with the lower gallery and steam may be introduced thereto via the drill line 28, which may extend from the surface 18 or from galleries formed in the limestone 22.
In another alternative, a series of vertical steam injection wells 30 may be formed extending from the surface 18 to the oil sands formation 12 through which steam is introduced to the formation. The steam introduced by either alternative, or both, if desired, causes bitumen to flow in the formation 12 and drain by gravity into the producing well 10 where, as described above, the bitumen is emulsified by dilute alkali for transportation to the surface 18 or to galleries in the limestone 22, to permit recovery of the bitumen therefrom and recycle of the alkali.
In summary of this disclosure, the present invention provides a novel manner of 1n situ recovery of bitumen from oil sands using dilute alkali. Modifications are possible within the scope of this invention.
The present invention relates to the recovery of bitumen from oil sands by an in-sltu procedure.
One procedure which has been proposed for the recovery of bitumen from subterranean oil sands deposits is by employing dilute alkali, such as a 0.1 wt% sodium hydroxide solution, to emulsify and remove bitumen from the formation, with the resulting emulslon being broken at the surface for recovery of the bitumen.
One problem that can be encountered with such procedure is channelling between the injector and producer wells. After an initial production of bitumen, a pathway of clean sand is produced between the wells.
As more alkali is pumped into the formation, it takes the path of least resistance and continues to flow through the bitumen-depleted pathway and out of the producer well. Accordingly, there is an initial production of rich bitumen-in-oil emulsion that becomes progressively thinner as pumping proceeds.
In accordance with the present invention, we provide an improved procedure for the in-situ recovery of bitumen from oil sands deposits by a horizontal gallery provided in an oil sands formation arrangement in which dilute aqueous alkali is pumped through the gallery to emulsify bitumen therefrom and in which some means is provided to cause bitumen to flow and drain from the formation into the gallery, such as heat from steam pumped into an upper gallery or otherwise into the formation above the gallery. As bitumen flows by gravity into the gallery, it is emulsified by the alkali and then is pumped to the surface for recovery of the bitumen.
The horizontal gallery or well from which the bitumen is recovered may be provided in any convenient manner in the formation, such as by suitable drilling procedures using conventional techniques or hydraulic jetting techniques. Such horizontal gallery may have any desired length and may be substantially vertically 2~723 aligned with an upper gallery or well for introduction of steam. Steam may be pumped into the upper well through the drill line used to form the gallery. Alternatively, steam may be introduced by a plurality of steam injection wells drilled vertically down from the top of the formation.
The bitumen flows through the formation under the influence of the heat introduced to the formation by the steam to the lower gallery wherein it is emulsified with the dilute alkali. Such lower gallery may be a Elow through one, whereby dilute alkali flows through the gallery and the upwardly to the surface, or may be blind ended, in which case dilute alkali can be introduced through an insert pipe extending along the gallery and emulsion is recovered through the annular gap.
perforated outer pipe may be employed or omitted, as desired. A "mud motor" used in the drilling operation may be left at the end of the drill steam during production from the formation.
The emulsion so formed in the lower gallery has a low viscosity and can be readily pumped to the surface, thereby reducing pumping costs. The concentration of bitumen in the emulsion may be controlled by the pumping rate of dilute alkali through the lower gallery emulsion formation may be effected at temperature up to 100C or higher. Heat 109s from the emulsion would not significantly increase the viscosity of the emulsion during pumping since the emulsion has the characteristics of water. The use of dilute alkali minimizes well corrosion.
Further processing of the emulsion is required at the surface to break the emulsion, for example by dilution and/or addition of calcium hydroxide. Bitumen recovery then may be made by flotation or gravity separation, depending on the density of the bitumen.
7 2 ~
Clean up of bitumen, for example, by dilution and centrifugation, may be facilitated by high pH, as descrlbed in our CP 1,243,468. Further incremental addition of calcium hydroxide flocculates any residual mineral materlal and, after removal of the flocculated materials by setting or any suitable mechanical means, provides a clean sodium hydroxide solution for recycle to the well.
Quantities of sodium carbonate, generally 0 to 500 ppm, may be added to the recycle stream to remove any excess free calcium ion remaining in the recovered alkaline solution and to remove any free calcium ion that might be present in the connate water.
The procedure of formation of emulsion from bitumen, transportation to another location, in this case the surface, and processing of the bitumen is somewhat analogous to the procedure described in our Canadian Patent No. 1,137,005. The process conditions described therein for emulsion formation and subsequent bitumen recovery may be employed in the present invention.
The procedure is characterized by a low chemical cost for the calcium hydroxide used in emulsion breaking and clean up and for make up quantities of sodium hydroxide.
The invention is described further, by way of illustration, with reference to the accompanying drawings, in which:
Figure 1 illustrates the method of the present invention with two alternative manners of introduction of steam being illustrated; and Figure 2 illustrates a alternative configuration for the producing well gallery.
Referring to the drawings, a horizontal producing well or gallery 10 is drilled into a lower region of an oil sands formation 12. Such producing well or gallery 10 may comprise an outer perforated casing 14 and an 21 ~8 72~3 inner feed plpe 16. Alternatively, the outer perforated casing 14 may be omitted.
Dilute alkali flows from the surface 18 through the drlll line 20, whlch may extend through overburden 21 from the surface 18 or from galleries formed in limestone 22 underlying the oil sands formation 12. Such dilute alkali flows through the inner pipe 16 in the horizontal gallery or well 14 and exits adjacent the blind end of the gallery and then flows countercurrently in the outer annulus 24, emulsifying bitumen draining into the gallery 10 .
Bitumen may be caused to flow from the formation 12 by gravity into the lower gallery by any suitable means.
Most conveniently, steam is used in this regard, which may be introduced to the upper region cf the oil sands formation 12 above the lower gallery or well 10. In one alternative, a second gallery or well 26 is provided in the formation 12 aligned vertically with the lower gallery and steam may be introduced thereto via the drill line 28, which may extend from the surface 18 or from galleries formed in the limestone 22.
In another alternative, a series of vertical steam injection wells 30 may be formed extending from the surface 18 to the oil sands formation 12 through which steam is introduced to the formation. The steam introduced by either alternative, or both, if desired, causes bitumen to flow in the formation 12 and drain by gravity into the producing well 10 where, as described above, the bitumen is emulsified by dilute alkali for transportation to the surface 18 or to galleries in the limestone 22, to permit recovery of the bitumen therefrom and recycle of the alkali.
In summary of this disclosure, the present invention provides a novel manner of 1n situ recovery of bitumen from oil sands using dilute alkali. Modifications are possible within the scope of this invention.
Claims (23)
1. A method for the recovery of hydrocarbons from a hydrocarbon deposit having an aquifer at the base of the hydrocarbon deposit, the method comprising the steps of:
injecting a hydrocarbon solvent in the vapour phase along a predominantly horizontal injection well into the aquifer to mobilize hydrocarbons in the hydrocarbon deposit; and producing mobilized hydrocarbons from the hydrocarbon deposit.
injecting a hydrocarbon solvent in the vapour phase along a predominantly horizontal injection well into the aquifer to mobilize hydrocarbons in the hydrocarbon deposit; and producing mobilized hydrocarbons from the hydrocarbon deposit.
2. The method of claim 1 in which the mobilized hydrocarbons are produced from the aquifer.
3. The method of claim 1 in which the hydrocarbon solvent is injected into a pre-existing aquifer.
4. The method of claim 1 in which the mobilized hydrocarbons are produced along a predominantly horizontal production well in the aquifer.
5. The method of claim 4 in which the hydrocarbon solvent is injected along an array of predominantly horizontal injection wells spaced from each other in the aquifer and the mobilized hydrocarbons are produced along an array of horizontal production wells in the aquifer, and the production and injection wells alternate.
6. The method of claim 1 further including initially creating an aquifer at the base of the hydrocarbon deposit by:
hydraulic fracturing of the hydrocarbon deposit to create a horizontal fracture in the hydrocarbon deposit; and injecting water into the horizontal fracture.
hydraulic fracturing of the hydrocarbon deposit to create a horizontal fracture in the hydrocarbon deposit; and injecting water into the horizontal fracture.
7. The method of claim 1 in which the hydrocarbon solvent in the vapour phase is injected into the hydrocarbon deposit at about the hydrocarbon deposit temperature.
8. The method of claim 3 in which the hydrocarbon solvent is injected along an array of predominantly horizontal injection wells spaced from each other in the aquifer and the mobilized hydrocarbons are produced along an array of horizontal production wells in the aquifer, and the production and injection wells alternate..
9. The method of claim 1 in which the hydrocarbon solvent is selected from the group consisting of ethane, propane and butane.
10. The method of claim 1 further including injecting the hydrocarbon solvent into the aquifer along with a diluent gas that is less soluble in the hydrocarbon deposit than the hydrocarbon solvent.
11. The method of claim 1 in which the solvent vapour is dry.
12. The method of claim 1 further including producing free gas along with the mobilized hydrocarbons.
13. Apparatus for the recovery of hydrocarbons from a hydrocarbon deposit having an aquifer at the base of the hydrocarbon deposit, the apparatus comprising:
a source of hydrocarbon solvent vapour;
a first injection well drilled horizontally into the aquifer, the injection well having a portion open to fluid communication with the aquifer and being connected to the source of hydrocarbon solvent vapour;
and a first production well drilled horizontally into one of the aquifer and the deposit, and spaced horizontally from the injection well, the first production well including a pump for pumping oil from the well.
a source of hydrocarbon solvent vapour;
a first injection well drilled horizontally into the aquifer, the injection well having a portion open to fluid communication with the aquifer and being connected to the source of hydrocarbon solvent vapour;
and a first production well drilled horizontally into one of the aquifer and the deposit, and spaced horizontally from the injection well, the first production well including a pump for pumping oil from the well.
14. The apparatus of claim 13 further including a solvent stripper connected between the first injection well and the first production well.
15. The apparatus of claim 13 further including a second injection well drilled into and lying horizontally in the aquifer spaced from the first production well, with the first production well located between the first and second injection wells.
16. The apparatus of claim 13 further including a gas recovery system attached to the production well.
17. A method for the production of hydrocarbons from a hydrocarbon deposit having a base, the method comprising:
drilling a first horizontal well into the base of the hydrocarbon deposit;
drilling a second horizontal well into the base of the hydrocarbon deposit spaced from the first horizontal well;
fracturing the base of the hydrocarbon deposit to form horizontal fractures extending between the first horizontal well and the second horizontal well;
injecting a saturated hydrocarbon solvent vapour into the base of the hydrocarbon deposit through the first horizontal well; and producing hydrocarbons from the second horizontal well.
drilling a first horizontal well into the base of the hydrocarbon deposit;
drilling a second horizontal well into the base of the hydrocarbon deposit spaced from the first horizontal well;
fracturing the base of the hydrocarbon deposit to form horizontal fractures extending between the first horizontal well and the second horizontal well;
injecting a saturated hydrocarbon solvent vapour into the base of the hydrocarbon deposit through the first horizontal well; and producing hydrocarbons from the second horizontal well.
18. The method of claim 17 in which the hydrocarbon solvent vapour is selected from the group consisting of ethane, propane and butane.
19. The method of claim 18 in which the hydrocarbon deposit is a bitumen deposit.
20. The method of claim 17 in which fracturing the base of the hydrocarbon deposit includes:
injecting a fracturing fluid into the base of the hydrocarbon deposit from the first horizontal well.
injecting a fracturing fluid into the base of the hydrocarbon deposit from the first horizontal well.
21. The method of claim 17 in which injecting a saturated hydrocarbon solvent vapour into the base of the hydrocarbon deposit through the first horizontal well includes initially injecting a mixture of the hydrocarbon solvent vapour and a diluent gas into the base of the hydrocarbon deposit.
22. A method for the recovery of hydrocarbons from a hydrocarbon deposit having a aquifer at the base of the hydrocarbon deposit, the method comprising the steps of:
injecting a hydrocarbon solvent in the vapour phase into the aquifer at about the hydrocarbon deposit temperature to mobilize hydrocarbons in the hydrocarbon deposit; and producing mobilized hydrocarbons from the hydrocarbon deposit.
injecting a hydrocarbon solvent in the vapour phase into the aquifer at about the hydrocarbon deposit temperature to mobilize hydrocarbons in the hydrocarbon deposit; and producing mobilized hydrocarbons from the hydrocarbon deposit.
23. The method of claim 22 in which the aquifer is pre-existing.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002108723A CA2108723A1 (en) | 1993-10-19 | 1993-10-19 | In-situ bitumen recovery from oil sands |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002108723A CA2108723A1 (en) | 1993-10-19 | 1993-10-19 | In-situ bitumen recovery from oil sands |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2108723A1 true CA2108723A1 (en) | 1995-04-20 |
Family
ID=4152467
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002108723A Abandoned CA2108723A1 (en) | 1993-10-19 | 1993-10-19 | In-situ bitumen recovery from oil sands |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA2108723A1 (en) |
Cited By (13)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2013166586A1 (en) * | 2012-05-07 | 2013-11-14 | Nexen Energy Ulc | Satellite steam-assisted gravity drainage with oxygen (sagdox) system for remote recovery of hydrocarbons |
| US8602098B2 (en) | 2010-02-16 | 2013-12-10 | Exxonmobil Upstream Research Company | Hydrate control in a cyclic solvent-dominated hydrocarbon recovery process |
| US8684079B2 (en) | 2010-03-16 | 2014-04-01 | Exxonmobile Upstream Research Company | Use of a solvent and emulsion for in situ oil recovery |
| US8752623B2 (en) | 2010-02-17 | 2014-06-17 | Exxonmobil Upstream Research Company | Solvent separation in a solvent-dominated recovery process |
| US8788250B2 (en) | 2007-05-24 | 2014-07-22 | Exxonmobil Upstream Research Company | Method of improved reservoir simulation of fingering systems |
| US8899321B2 (en) | 2010-05-26 | 2014-12-02 | Exxonmobil Upstream Research Company | Method of distributing a viscosity reducing solvent to a set of wells |
| US8967282B2 (en) | 2010-03-29 | 2015-03-03 | Conocophillips Company | Enhanced bitumen recovery using high permeability pathways |
| US9488040B2 (en) | 2013-12-03 | 2016-11-08 | Exxonmobil Upstream Research Company | Cyclic solvent hydrocarbon recovery process using an advance-retreat movement of the injectant |
| US10041340B2 (en) | 2013-12-19 | 2018-08-07 | Exxonmobil Upstream Research Company | Recovery from a hydrocarbon reservoir by conducting an exothermic reaction to produce a solvent and injecting the solvent into a hydrocarbon reservoir |
| US10487636B2 (en) | 2017-07-27 | 2019-11-26 | Exxonmobil Upstream Research Company | Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes |
| US11002123B2 (en) | 2017-08-31 | 2021-05-11 | Exxonmobil Upstream Research Company | Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation |
| US11142681B2 (en) | 2017-06-29 | 2021-10-12 | Exxonmobil Upstream Research Company | Chasing solvent for enhanced recovery processes |
| US11261725B2 (en) | 2017-10-24 | 2022-03-01 | Exxonmobil Upstream Research Company | Systems and methods for estimating and controlling liquid level using periodic shut-ins |
-
1993
- 1993-10-19 CA CA002108723A patent/CA2108723A1/en not_active Abandoned
Cited By (13)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US8788250B2 (en) | 2007-05-24 | 2014-07-22 | Exxonmobil Upstream Research Company | Method of improved reservoir simulation of fingering systems |
| US8602098B2 (en) | 2010-02-16 | 2013-12-10 | Exxonmobil Upstream Research Company | Hydrate control in a cyclic solvent-dominated hydrocarbon recovery process |
| US8752623B2 (en) | 2010-02-17 | 2014-06-17 | Exxonmobil Upstream Research Company | Solvent separation in a solvent-dominated recovery process |
| US8684079B2 (en) | 2010-03-16 | 2014-04-01 | Exxonmobile Upstream Research Company | Use of a solvent and emulsion for in situ oil recovery |
| US8967282B2 (en) | 2010-03-29 | 2015-03-03 | Conocophillips Company | Enhanced bitumen recovery using high permeability pathways |
| US8899321B2 (en) | 2010-05-26 | 2014-12-02 | Exxonmobil Upstream Research Company | Method of distributing a viscosity reducing solvent to a set of wells |
| WO2013166586A1 (en) * | 2012-05-07 | 2013-11-14 | Nexen Energy Ulc | Satellite steam-assisted gravity drainage with oxygen (sagdox) system for remote recovery of hydrocarbons |
| US9488040B2 (en) | 2013-12-03 | 2016-11-08 | Exxonmobil Upstream Research Company | Cyclic solvent hydrocarbon recovery process using an advance-retreat movement of the injectant |
| US10041340B2 (en) | 2013-12-19 | 2018-08-07 | Exxonmobil Upstream Research Company | Recovery from a hydrocarbon reservoir by conducting an exothermic reaction to produce a solvent and injecting the solvent into a hydrocarbon reservoir |
| US11142681B2 (en) | 2017-06-29 | 2021-10-12 | Exxonmobil Upstream Research Company | Chasing solvent for enhanced recovery processes |
| US10487636B2 (en) | 2017-07-27 | 2019-11-26 | Exxonmobil Upstream Research Company | Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes |
| US11002123B2 (en) | 2017-08-31 | 2021-05-11 | Exxonmobil Upstream Research Company | Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation |
| US11261725B2 (en) | 2017-10-24 | 2022-03-01 | Exxonmobil Upstream Research Company | Systems and methods for estimating and controlling liquid level using periodic shut-ins |
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