WO2010084369A9 - Procédé pour extraire du pétrole brut visqueux à partir d'un réservoir - Google Patents
Procédé pour extraire du pétrole brut visqueux à partir d'un réservoir Download PDFInfo
- Publication number
- WO2010084369A9 WO2010084369A9 PCT/IB2009/000253 IB2009000253W WO2010084369A9 WO 2010084369 A9 WO2010084369 A9 WO 2010084369A9 IB 2009000253 W IB2009000253 W IB 2009000253W WO 2010084369 A9 WO2010084369 A9 WO 2010084369A9
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- steam
- injection
- production
- foam
- hydrocarbons
- Prior art date
Links
- 238000000034 method Methods 0.000 title claims abstract description 52
- 239000003208 petroleum Substances 0.000 title description 5
- 238000004519 manufacturing process Methods 0.000 claims abstract description 73
- 239000006260 foam Substances 0.000 claims abstract description 63
- 238000002347 injection Methods 0.000 claims abstract description 58
- 239000007924 injection Substances 0.000 claims abstract description 58
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 53
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 53
- 239000002245 particle Substances 0.000 claims abstract description 43
- 238000009434 installation Methods 0.000 claims abstract description 26
- 238000010793 Steam injection (oil industry) Methods 0.000 claims abstract description 11
- 239000004094 surface-active agent Substances 0.000 claims description 25
- 239000007789 gas Substances 0.000 claims description 23
- 239000000203 mixture Substances 0.000 claims description 9
- 239000000243 solution Substances 0.000 claims description 9
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 8
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 6
- 229910052757 nitrogen Inorganic materials 0.000 claims description 4
- 229910021532 Calcite Inorganic materials 0.000 claims description 3
- 125000001273 sulfonato group Chemical group [O-]S(*)(=O)=O 0.000 claims description 3
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims description 2
- 230000015572 biosynthetic process Effects 0.000 description 20
- 238000005755 formation reaction Methods 0.000 description 20
- 239000003921 oil Substances 0.000 description 19
- 239000004215 Carbon black (E152) Substances 0.000 description 15
- 230000035699 permeability Effects 0.000 description 15
- 238000010796 Steam-assisted gravity drainage Methods 0.000 description 12
- 230000005484 gravity Effects 0.000 description 12
- 239000011236 particulate material Substances 0.000 description 9
- 238000011084 recovery Methods 0.000 description 9
- 239000011148 porous material Substances 0.000 description 7
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 7
- 239000010426 asphalt Substances 0.000 description 5
- 238000011161 development Methods 0.000 description 4
- 230000000694 effects Effects 0.000 description 4
- 239000003027 oil sand Substances 0.000 description 4
- 239000012071 phase Substances 0.000 description 4
- 238000000605 extraction Methods 0.000 description 3
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 2
- 238000010795 Steam Flooding Methods 0.000 description 2
- 239000000295 fuel oil Substances 0.000 description 2
- 238000011065 in-situ storage Methods 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 239000007791 liquid phase Substances 0.000 description 2
- 230000000149 penetrating effect Effects 0.000 description 2
- 241000233805 Phoenix Species 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 125000004122 cyclic group Chemical group 0.000 description 1
- 230000006378 damage Effects 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 239000010881 fly ash Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 239000000377 silicon dioxide Substances 0.000 description 1
- 238000010025 steaming Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 238000010408 sweeping Methods 0.000 description 1
- 230000009466 transformation Effects 0.000 description 1
- 239000004711 α-olefin Substances 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
- E21B43/2406—Steam assisted gravity drainage [SAGD]
-
- 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
- E21B33/138—Plastering the borehole wall; Injecting into the formation
-
- 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
- E21B43/30—Specific pattern of wells, e.g. optimising the spacing of wells
- E21B43/305—Specific pattern of wells, e.g. optimising the spacing of wells comprising at least one inclined or horizontal well
Definitions
- the invention relates to the field of recovering viscous petroleum crude.
- Steam flooding of petroleum bearing formations has become one of the preferred methods of enhanced oil recovery. Heat reduces resistance of oil flow from a reservoir to a production well over a wide range of formation permeability by decreasing the oil viscosity. Further, steam injection enhances the natural reservoir pressure, and increases the differential pressure between oil in the reservoir and the producing well bore.
- a petroleum reservoir is inherently inhomogeneous. Because of the differences of permeability in a reservoir, it is common practice to inject a foam forming surfactant in a reservoir with the injected steam, in order to block the higher permeability zones. The desired result is to divert steam from the oil depleted, high permeability channels into the less permeable zone having been not yet swept and then containing higher oil saturation. At the end, the sweep efficiency is highly improved.
- Foam in porous media can be defined as a dispersion of gas phase in a liquid phase.
- the gas phase is broken into discrete bubbles, separated by liquid films called lamellae (Rossen 1996, Foams In Enhanced Oil Recovery, In Foams : Theory Measurements and Application, R.K. Prud'homme and S. Khan (eds.). New York : Marcel Dekker. ).
- lamellae In porous medium, the lamellae between bubbles greatly restrict the mobility of gas. Thus the number and the size of these lamellae govern the mobility of gas.
- Foam can be generated in-situ, by injection into a porous medium of a solution comprising steam (or water and gas mixture) and surfactant. Stable foam can also be generated at the surface, and then injected into the reservoir.
- "Foam Generation” is a transformation from a state of high gas mobility (weak foam or no foam) to one of low mobility (strong foam). Foam generation is a process where the rate of lamellae creation greatly exceeds the rate of lamellae destruction.
- US 5 052 487 describes an improved method for enhanced oil recovery using steam and surfactant.
- An alpha olefin surfactant is injected with steam to form foam in areas of reduced oil concentration, and thereby divert steam to areas having higher oil concentration. At the end, the sweep efficiency is increased.
- SAGD process where a surfactant and a non-condensable gas (for instance nitrogen) are added while injecting steam into an upper horizontal well once steam breakthrough occurs in an interwell region.
- a surfactant and a non-condensable gas for instance nitrogen
- the increased pressure gradient adds to the gravity force thereby providing a greater interstitial oil velocity which increases oil drainage between well during start-up.
- foam is generated in situ.
- the invention consequently provides a method for extracting hydrocarbons from a reservoir comprising:
- the steam is injected through one or several vertical injection wellbores.
- the hydrocarbons are collected in one or several horizontal production wellbores in the production region.
- the steam is injected from one or several horizontal injection wellbores.
- the hydrocarbons are collected in one or several horizontal production wellbores in the production region.
- the production wellbores are parallel or perpendicular to the injection wellbores.
- the steam is injected from an upper portion of a wellbore and the hydrocarbons are collected in a lower portion of this same wellbore.
- the method further comprises the steps of:
- the method further comprises the steps of
- the surfactant is a sulfonate.
- the surfactant is an alkylayl sulfonate.
- the mixture of foam and particles is injected continuously, sequentially or from time to time.
- the gas-added to generate foam is a non condensable gas.
- the non condensable gas is methane.
- the non-condensable gas is nitrogen.
- the particle size is comprised between 0.1 and 10 ⁇ .
- the particles have a varying particle size.
- the particles are calcite.
- the particles are Fly Ashes.
- the injection of steam is continuous or discontinuous.
- Figures 1 to 5 show examples of a hydrocarbon production installation.
- the invention provides a method for hydrocarbon production comprising injection of steam into an injection region of a reservoir and collection of hydrocarbons from a production region of the reservoir.
- the hydrocarbon production region is lower down in the reservoir than the steam injection region.
- the method further comprises injecting a mixture comprising foam and particles into the injection region.
- foam is generated by mixing a surfactant solution with gas.
- the foam is then mixed with particulate material.
- a surfactant solution is mixed with particulate material, and then mixed with gas to generate foam.
- FIGS 1 -5 illustrate installations in which the hydrocarbon production method can be implemented.
- Figures 1 -5 show reservoirs 10 made up of strata which are inclined to a greater or lesser degree.
- the hydrocarbons are heavy oils, which, due to their high viscosity and low mobility, cannot be extracted simply by conventional manner.
- SAGD Steam Assisted Gravity Drainage
- a single vertical well is used for steam injection and hydrocarbon recovery.
- steam is injected in a vertical well located in the upper, part of a formation and hydrocarbons are recovered in a lower horizontal well.
- Steam is injected into a wellbore to heat an adjacent subterranean formation. After a start-up phase for which steam is circulated in both upper well and lower well in order to heat mainly by conduction the interwell region, steam is continuously injected into the upper well. Around and above the injection well, a steam chamber grows. The injected steam flows into the steam chamber and eventually comes into contact with oil sand at its edge. The steam then releases its latent heat to the oil sand, the oil heats up, its viscosity drops, and it flows with water condensate under gravity down the inclined chamber edge to the production well. As the mobilized bitumen drains downwards, the freed pore space is continually filled with steam. The steam chamber expands.
- the hydrocarbons are collected at least in part by gravity.
- the hydrocarbon production region is lower down in the reservoir than the steam injection region.
- the hydrocarbons have a tendency to flow at the periphery of the steam chamber.
- the hydrocarbons are collected then at least in part under gravity in the production region which is lower down in the reservoir.
- Figures 1-5 also show that the injection and production regions are remote from each other within the reservoir.
- the reservoir may be made up of strata having various permeability values. When steam is injected, this will have a tendency to preferentially go into the most permeable areas of the reservoir. The least permeable regions are not readily accessible to the steam. This leads to the development of a heterogeneous steam chamber, which tends to enlarge. The least permeable regions are consequently exploited less effectively. It then becomes extremely difficult to subsequently be able to recover hydrocarbons from these regions.
- foam incorporates particles.
- the particles are carried by the foam and will migrate into the reservoir through the pores.
- the pores will then get filled by particles until the pore entrances get blocked off, with a consequent decrease in permeability.
- the steam will be forced into regions or strata that are less permeable.
- foam as the carrier makes it possible to carry the particles into the deep regions of the reservoir.
- the foam mixed with particulate material can be injected continuously with steam into the reservoir.
- the mixture can be constantly injected.
- the injection of foam with particles can be discontinuous, that is, the injection can be stayed.
- the injection can cyclic: during a first stage, steam will be injected alone in the injection well and then, a slug of foam mixed with particles will be injected.
- the mixture may also be injected from time to time, i.e., injected irregularly.
- the discontinuous injection may be predetermined.
- Which mode of injection is used depends on the type of heterogeneity to a be dealt with (far and diffuse or near and local) and on processing cost optimization.
- foam is generated by mixing a surfactant solution with gas.
- the foam is then mixed with particulate material.
- a surfactant solution is mixed with particulate material, and then mixed with gas to generate foam.
- a thermally stable foam forming surfactant is required.
- Such surfactant is described in the publication SPE 13 572 "Thermal Stability of Surfactants for Steamfiood Applications" presented at the International Symposium on Oilfield and Geothermal Chemistry held in Phoenix , Arizona, April 9-11 1985. .
- sulfonates surfactants are disclosed in European patent application EP-A- 1,604,094 can be chosen, as well as surfactant as disclosed m EP -A-0, 681, 460.
- the method makes it possible to directly modify permeability of the reservoir.
- particle size is smaller than the size of the reservoir pores, in order to fill the pores.
- the particle size is comprised between 0.1 and ⁇ ⁇ depending on reservoir permeability.
- Calcite particles can also be chosen, as well as fly ashes.
- the injected steam has a high water content, in order to generate foam with a sufficient water content. Because the particles are trapped in the liquid phase of the foam, it is preferable to provide a foam composition with a sufficient liquid content to ensure a better penetration of the foam and particles into the reservoir.
- a non condensable gas is injected along with steam and surfactant.
- the non condensable gas can be nitrogen, or methane.
- FIGS 1-5 illustrate some examples of hydrocarbon production installations. These installations notably comprise equipment, which is not shown, for injecting particle-bearing foam and steam, as well as equipment for hydrocarbon extraction.
- Figure 1 shows one example of a hydrocarbon production installation.
- the installation 12 comprises a wellbore 14 that penetrates into reservoir 10.
- Wellbore 14 is substantially vertical.
- Wellbore 14 extends over several hundreds of meters in a reservoir, passing through strata of differing permeability.
- the installation 12 of Figure 1 has the particular feature of having one single injection and production wellbore.
- the steam and foam injection region is in the upper portion of wellbore 14 and the production region is in the lower portion of wellbore 14.
- the hydrocarbon production region is at a lower level than the steam injection region.
- FIG. 1 further shows a steam chamber 18 in the process of formation.
- Steam chamber 18 causes the hydrocarbons at the outer regions of the chamber to heat up.
- the hydrocarbons move in a direction of arrows 20 towards the production region at the lower portion of wellbore 14.
- the hydrocarbons are drained by gravity towards the production region.
- foam incorporating particles is injected along with the steam as a way of forcing the steam towards the less permeable regions. This has an effect of enlarging the steam chamber thereby increasing the volume of hydrocarbons extracted at this site.
- the value of this type of installation is its simplicity of implementation.
- FIG 2 shows another example of a hydrocarbon production installation.
- installation 12 has a plurality of wellbores 14 penetrating into reservoir 10.
- the wellbores 14 are substantially vertical. They extend over several hundreds of meters into the reservoir and pass through strata of differing permeability.
- the installation 12 in Figure 2 has the particular feature of having one single production wellbore 22.
- This wellbore 22 is horizontal and extends below each one of the injection wellbores 14.
- the wellbores are substantially in the same plane.
- Production wellbore 22 is in a lower region than injection wellbores 14.
- FIG. 2 further shows a steam chamber 18 in the course of formation for each one of the injecting wellbores 14.
- Steam chamber 18 causes the hydrocarbons in the outer regions of the chamber to heat up. The hydrocarbons follow the path shown by arrows 20 towards the collection regions where production wellbore 22 is located. The hydrocarbons drain under gravity towards the production region.
- foam incorporating particles is injected with the steam as a way of forcing the steam towards less permeable regions. This makes it possible to extend the steam chambers thereby increasing the volumes of hydrocarbon extracted at this site. Further, the use of foam incorporating particles makes it possible to reduce the risk of the formation of breakthrough paths between the injection wellbores 14 and production wellbore 22. The value of such an installation is that of being able to cover a larger field area while limiting the number of production wellbores.
- FIG 3 shows another example of an installation for producing hydrocarbons.
- Installation 12 in Figure 3 is similar to the installation in Figure 1 as regards the injection wellbores 14 but differs as regards its production bores.
- Installation 12 in figure 3 comprises a plurality of production wellbores 22. These production wellbores 22 are in a lower region than the injection wellbores 14.
- the production wellbores 22 are additionally offset with respect to injection wellbores 14.
- the production wellbores 22 are substantially perpendicular to the plane of Figure 3 and are shown in cross section.
- the production wellbores 22 are horizontal. In Figure 3, only one plane containing injection wellbores 14 is shown; additional wellbores 14 on planes parallel to the plane of Figure 3 are arranged along the production bores 22.
- FIG. 3 also shows a steam chamber 18 in the process of formation for each of the injection wellbores 14.
- Steam chamber 18 causes the hydrocarbons in the outer regions of the chamber to heat up. The hydrocarbons follow the path indicated by the arrows 20 down towards the production region in which the production bores 22 are located. Hydrocarbons not only drain by gravity towards the production region which is lower than the injection region, but are also drained by sweeping towards the production region which is not in line with the injection region.
- foam incorporating particles is injected with the steam as a way of forcing the steam towards the less permeable regions. This makes it possible to extend the steam chambers thereby increasing the volume of hydrocarbon extracted at this site.
- foam incorporating particles reduces the risk of breakthrough paths being set up between the injection wellbores 14 and production wellbores 22.
- the value of such an installation is that of being able to space the injection wellbores 14 when compared to the injection wellbores 14 shown in figure 2. This allows a larger area to be covered by an installation while limiting the number of injection wellbores.
- Figure 4 shows another example of an installation for producing hydrocarbons.
- the installation 12 comprises a wellbore 14 penetrating into reservoir 10.
- Wellbore 14 is substantially horizontal. It extends over several hundreds of metres in the reservoir and passes through strata of differing permeability.
- This installation 12 in Figure 4 has the particular feature of including a production wellbore 22 which is also horizontal.
- Production wellbore 22 is in a region which is lower than injection wellbore 14.
- SAGD steam-assisted gravity drainage
- the injection 14 and production 22 wellbores are substantially parallel and are separated by several metres.
- Figure 4 further shows a steam chamber 18 in the process of being formed. Steam chamber 18 causes the hydrocarbons at the outer regions of the chamber to heat up. The hydrocarbons follow paths shown by the arrows 20 towards the production region which is lower down than wellbore 14.
- injection wellbores 14 and production wellbores 22 which are horizontal, but not parallel to each other but rather mutually perpendicular.
- the injection wellbores 14 are however perpendicular to the production wellbores 22.
- the injection 14 and production 22 wellbores may be substantially horizontal in the injection and production regions. Nevertheless, the wellbores are also provided with a non-horizontal portion linking these regions with the surface of the reservoir.
- the production wellbores may be at least partially horizontal in that at least a portion of the wellbore is horizontal. Nevertheless, another portion (as shown in figures 4 and 5) of the wellbore is not horizontal to link the horizontal portion to the surface of 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
L'invention porte sur un procédé pour extraire des hydrocarbures à partir d'un réservoir, lequel procédé comprend la disposition d'une installation comprenant au moins un puits de forage s'étendant à l'intérieur du réservoir, l'injection de vapeur dans une région d'injection de celui-ci, la collecte d'hydrocarbures dans une région de production, la région de production d'hydrocarbures étant en dessous de la région d'injection de vapeur, et l'injection d'une mousse incorporant des particules dans la région d'injection. Le procédé permet également une meilleure régulation de la propagation de vapeur à l'intérieur du réservoir et une meilleure exploitation du réservoir.
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/IB2009/000253 WO2010084369A1 (fr) | 2009-01-20 | 2009-01-20 | Procédé pour extraire du pétrole brut visqueux à partir d'un réservoir |
CA2748980A CA2748980C (fr) | 2009-01-20 | 2009-01-20 | Procede pour extraire du petrole brut visqueux a partir d'un reservoir |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/IB2009/000253 WO2010084369A1 (fr) | 2009-01-20 | 2009-01-20 | Procédé pour extraire du pétrole brut visqueux à partir d'un réservoir |
Publications (2)
Publication Number | Publication Date |
---|---|
WO2010084369A1 WO2010084369A1 (fr) | 2010-07-29 |
WO2010084369A9 true WO2010084369A9 (fr) | 2011-05-05 |
Family
ID=41395400
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/IB2009/000253 WO2010084369A1 (fr) | 2009-01-20 | 2009-01-20 | Procédé pour extraire du pétrole brut visqueux à partir d'un réservoir |
Country Status (2)
Country | Link |
---|---|
CA (1) | CA2748980C (fr) |
WO (1) | WO2010084369A1 (fr) |
Families Citing this family (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
FR2970880B1 (fr) | 2011-01-27 | 2013-02-08 | Rhodia Operations | Agents moussants phosphores stables a haute temperature |
GB2499224A (en) * | 2012-02-09 | 2013-08-14 | Paul Bernard Lee | Steam assisted gravity drainage hydrocarbon production |
US9845669B2 (en) | 2014-04-04 | 2017-12-19 | Cenovus Energy Inc. | Hydrocarbon recovery with multi-function agent |
FR3021052A1 (fr) | 2014-05-15 | 2015-11-20 | Rhodia Operations | Stabilisateurs de mousse de type aminosulfonate |
BR112017003542A2 (pt) | 2014-08-22 | 2017-12-05 | Stepan Co | método para aprimorar uso de vapor em um processo de drenagem gravitacional assistida com vapor (sagd) para recuperação de óleo bruto |
Family Cites Families (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3713489A (en) * | 1970-09-08 | 1973-01-30 | Amoco Prod Co | Plugging of fractures in underground formations |
US4470462A (en) * | 1981-08-03 | 1984-09-11 | Chevron Research Company | Foam and particulate material with steam for permeability alteration in subsurface formations |
US4445573A (en) * | 1982-11-04 | 1984-05-01 | Thermal Specialties Inc. | Insulating foam steam stimulation method |
US4501329A (en) * | 1983-04-18 | 1985-02-26 | Chevron Research Company | Non-abrasive particulate material for permeability alteration in subsurface formations |
FR2918102B1 (fr) * | 2007-06-29 | 2012-10-05 | Inst Francais Du Petrole | Methode de recuperation d'huile ou de bitume par injection d'un fluide de recuperation et d'un agent de diversion |
-
2009
- 2009-01-20 CA CA2748980A patent/CA2748980C/fr not_active Expired - Fee Related
- 2009-01-20 WO PCT/IB2009/000253 patent/WO2010084369A1/fr active Application Filing
Also Published As
Publication number | Publication date |
---|---|
CA2748980C (fr) | 2015-10-20 |
CA2748980A1 (fr) | 2010-07-29 |
WO2010084369A1 (fr) | 2010-07-29 |
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