CA3145266A1 - Foaming formulation comprising sulphonates for oil recovery - Google Patents
Foaming formulation comprising sulphonates for oil recovery Download PDFInfo
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- CA3145266A1 CA3145266A1 CA3145266A CA3145266A CA3145266A1 CA 3145266 A1 CA3145266 A1 CA 3145266A1 CA 3145266 A CA3145266 A CA 3145266A CA 3145266 A CA3145266 A CA 3145266A CA 3145266 A1 CA3145266 A1 CA 3145266A1
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- 239000000203 mixture Substances 0.000 title claims abstract description 91
- 238000005187 foaming Methods 0.000 title claims abstract description 15
- 238000011084 recovery Methods 0.000 title claims description 15
- 125000001273 sulfonato group Chemical group [O-]S(*)(=O)=O 0.000 title claims 6
- 238000009472 formulation Methods 0.000 title description 2
- 238000000034 method Methods 0.000 claims abstract description 26
- 239000004711 α-olefin Substances 0.000 claims abstract description 16
- -1 alkyl ether carboxylate Chemical class 0.000 claims abstract description 13
- 150000008055 alkyl aryl sulfonates Chemical class 0.000 claims abstract description 4
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims abstract description 4
- 239000012736 aqueous medium Substances 0.000 claims abstract description 3
- 239000006260 foam Substances 0.000 claims description 25
- 230000015572 biosynthetic process Effects 0.000 claims description 23
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 19
- 238000002347 injection Methods 0.000 claims description 16
- 239000007924 injection Substances 0.000 claims description 16
- 239000004094 surface-active agent Substances 0.000 claims description 14
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 7
- 125000000217 alkyl group Chemical group 0.000 claims description 7
- 238000004519 manufacturing process Methods 0.000 claims description 7
- 239000003945 anionic surfactant Substances 0.000 claims description 6
- 239000012530 fluid Substances 0.000 claims description 5
- 238000005086 pumping Methods 0.000 claims description 5
- 238000010793 Steam injection (oil industry) Methods 0.000 claims description 4
- 125000004432 carbon atom Chemical group C* 0.000 claims description 3
- 238000009833 condensation Methods 0.000 claims description 3
- 230000005494 condensation Effects 0.000 claims description 3
- 229910001873 dinitrogen Inorganic materials 0.000 claims description 3
- QGZKDVFQNNGYKY-UHFFFAOYSA-O Ammonium Chemical compound [NH4+] QGZKDVFQNNGYKY-UHFFFAOYSA-O 0.000 claims description 2
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 claims description 2
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 claims description 2
- FYYHWMGAXLPEAU-UHFFFAOYSA-N Magnesium Chemical compound [Mg] FYYHWMGAXLPEAU-UHFFFAOYSA-N 0.000 claims description 2
- ZLMJMSJWJFRBEC-UHFFFAOYSA-N Potassium Chemical compound [K] ZLMJMSJWJFRBEC-UHFFFAOYSA-N 0.000 claims description 2
- 125000003342 alkenyl group Chemical group 0.000 claims description 2
- 239000011575 calcium Substances 0.000 claims description 2
- 229910052791 calcium Inorganic materials 0.000 claims description 2
- 150000001768 cations Chemical class 0.000 claims description 2
- 239000011777 magnesium Substances 0.000 claims description 2
- 229910052749 magnesium Inorganic materials 0.000 claims description 2
- 239000011591 potassium Substances 0.000 claims description 2
- 229910052700 potassium Inorganic materials 0.000 claims description 2
- 239000011734 sodium Substances 0.000 claims description 2
- 229910052708 sodium Inorganic materials 0.000 claims description 2
- 150000003467 sulfuric acid derivatives Chemical class 0.000 claims description 2
- 238000005243 fluidization Methods 0.000 claims 1
- 238000010796 Steam-assisted gravity drainage Methods 0.000 abstract description 10
- 150000004996 alkyl benzenes Chemical class 0.000 abstract description 2
- 229940077388 benzenesulfonate Drugs 0.000 abstract 1
- 238000005755 formation reaction Methods 0.000 description 19
- 239000003921 oil Substances 0.000 description 15
- 239000007789 gas Substances 0.000 description 13
- 238000000605 extraction Methods 0.000 description 12
- 239000010779 crude oil Substances 0.000 description 11
- 229930195733 hydrocarbon Natural products 0.000 description 11
- 150000002430 hydrocarbons Chemical class 0.000 description 11
- 239000004215 Carbon black (E152) Substances 0.000 description 6
- 230000008569 process Effects 0.000 description 6
- 150000003839 salts Chemical class 0.000 description 4
- 150000003871 sulfonates Chemical class 0.000 description 4
- 239000000295 fuel oil Substances 0.000 description 3
- 238000010794 Cyclic Steam Stimulation Methods 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 229910052799 carbon Inorganic materials 0.000 description 2
- 230000007423 decrease Effects 0.000 description 2
- SNRUBQQJIBEYMU-UHFFFAOYSA-N dodecane Chemical compound CCCCCCCCCCCC SNRUBQQJIBEYMU-UHFFFAOYSA-N 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 229910052757 nitrogen Inorganic materials 0.000 description 2
- 230000009467 reduction Effects 0.000 description 2
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 1
- 239000004480 active ingredient Substances 0.000 description 1
- 239000008186 active pharmaceutical agent Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 238000009987 spinning Methods 0.000 description 1
- 238000010408 sweeping Methods 0.000 description 1
- 230000009897 systematic effect Effects 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/584—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/592—Compositions used in combination with generated heat, e.g. by steam injection
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/594—Compositions used in combination with injected gas, e.g. CO2 orcarbonated gas
-
- 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
-
- 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
- E21B43/164—Injecting CO2 or carbonated water
-
- 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
- E21B43/168—Injecting a gaseous medium
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/2406—Steam assisted gravity drainage [SAGD]
- E21B43/2408—SAGD in combination with other methods
Abstract
The invention relates to foaming compositions which can be used in particular for EOR operations and especially for SAGD techniques, said foaming compositions comprising, in an aqueous medium M: - at least one alpha-olefin sulfonate (AOS); - at least one alkyl aryl sulfonate, preferably an alkyl benzene sulfonate (ABS); - and preferably an AGES or an alkyl ether carboxylate.
Description
FOAMING FORMULATIONS FOR ENHANCED OIL RECOVERY
The present invention relates to the recovery of crude oil from underground formations, and, more particularly, to oil recovery techniques which implement foaming formulations used at high temperature, typically in the presence of water steam (in particular to form a steam foam), in particular for the extraction of heavy oils.
During the extraction of oil from a hydrocarbon reservoir (oil reservoir such as a rock formation), the oil is typically driven out of a production well by the overpressure naturally prevailing within the reservoir according to a first step, known as "primary recovery". This primary recovery only makes it possible to access a small quantity of the oil contained in the reservoir, typically at most of the order of 10 to 15%, and it is then followed by a recovery step known as "secondary recovery" when the pressure of the reservoir becomes insufficient to drive out the oil still in place.
In some cases, the crude oil to be extracted has such a high viscosity that no primary recovery step can take place. In this unconventional case, more specific production methods allowing extraction are then used. These methods generally involve an increase in the temperature of the crude oil, which makes it possible to lower its viscosity and allow it to flow. The present invention relates to foaming compositions which can be used in particular in this context, especially for extracting heavy oils, which are typically crude oils having an API density of 22 AP I
or less and a viscosity of more than 100 cp.
The use of foams or foaming compositions most often aims at maximizing the sweeping of the subterranean formation, in particular to access the least accessible zones which would be little, if at all, swept by non-foaming compositions.
The invention relates, in particular, to the methods falling within what is commonly referred to as "Enhanced Oil Recovery" (EOR) (or "Enhanced Hydrocarbon Recovery" (EHR)) techniques.
In the context of the FOR, the foaming compositions used at high temperature
The present invention relates to the recovery of crude oil from underground formations, and, more particularly, to oil recovery techniques which implement foaming formulations used at high temperature, typically in the presence of water steam (in particular to form a steam foam), in particular for the extraction of heavy oils.
During the extraction of oil from a hydrocarbon reservoir (oil reservoir such as a rock formation), the oil is typically driven out of a production well by the overpressure naturally prevailing within the reservoir according to a first step, known as "primary recovery". This primary recovery only makes it possible to access a small quantity of the oil contained in the reservoir, typically at most of the order of 10 to 15%, and it is then followed by a recovery step known as "secondary recovery" when the pressure of the reservoir becomes insufficient to drive out the oil still in place.
In some cases, the crude oil to be extracted has such a high viscosity that no primary recovery step can take place. In this unconventional case, more specific production methods allowing extraction are then used. These methods generally involve an increase in the temperature of the crude oil, which makes it possible to lower its viscosity and allow it to flow. The present invention relates to foaming compositions which can be used in particular in this context, especially for extracting heavy oils, which are typically crude oils having an API density of 22 AP I
or less and a viscosity of more than 100 cp.
The use of foams or foaming compositions most often aims at maximizing the sweeping of the subterranean formation, in particular to access the least accessible zones which would be little, if at all, swept by non-foaming compositions.
The invention relates, in particular, to the methods falling within what is commonly referred to as "Enhanced Oil Recovery" (EOR) (or "Enhanced Hydrocarbon Recovery" (EHR)) techniques.
In the context of the FOR, the foaming compositions used at high temperature
2 may, for example, be used in steam foam processes.
According to another particular embodiment, foaming compositions, which can be used at high temperatures, may be used in steam extraction techniques known as "Steam Assisted Gravity Drainage" (SAGD). In these steam extraction processes (which will also be designated by "SAGD" in the remainder of the text for the sake of brevity), the hydrocarbons to be extracted are fluidized under the effect of the steam injection, then the mixture of fluidized oils and water formed by condensation of the steam is removed, for example by pumping. In general, the steam extraction (SAGD) implements two parallel horizontal wells, namely a first extraction well intended for pumping the hydrocarbons and a few meters above this extraction well, a second steam injection well. The steam circulating in the upper well heats up the hydrocarbons which, having become more fluid, flow by gravity into the extraction well located below, together with the condensed water, from where they are pumped out of the underground formation.
More generally, the use of FOR foams, in particular in the case where the aim is to extract a heavy oil, can also be implemented in Cyclic Steam Stimulation (CSS) processes (which are more commonly referred to as the "huff and puff" method), where the same well is used for injection and production. According to this method, steam is injected into the well for several weeks then the heated oil is extracted (typically by pumping) and this cycle of heating followed by extracting is then repeated.
An aim of the present invention is to provide foaming compositions which are suitable for use for the enhanced recovery of crude oil, in particular in steam foam processes, especially for carrying out steam extraction (SAGD).
To this end, specific foaming compositions, proposed according to the present invention, are based on a mixture of specific surfactants, which the inventors have now demonstrated that it makes it possible:
- to form stable foams including at high temperatures, in particular above 150 C, preferably between 200 and 300 C, in particular between 200 and 250 C
(typically of the order of 220 C), which corresponds to the temperature range suitable, in particular, for steam extraction processes (SAGD).
According to another particular embodiment, foaming compositions, which can be used at high temperatures, may be used in steam extraction techniques known as "Steam Assisted Gravity Drainage" (SAGD). In these steam extraction processes (which will also be designated by "SAGD" in the remainder of the text for the sake of brevity), the hydrocarbons to be extracted are fluidized under the effect of the steam injection, then the mixture of fluidized oils and water formed by condensation of the steam is removed, for example by pumping. In general, the steam extraction (SAGD) implements two parallel horizontal wells, namely a first extraction well intended for pumping the hydrocarbons and a few meters above this extraction well, a second steam injection well. The steam circulating in the upper well heats up the hydrocarbons which, having become more fluid, flow by gravity into the extraction well located below, together with the condensed water, from where they are pumped out of the underground formation.
More generally, the use of FOR foams, in particular in the case where the aim is to extract a heavy oil, can also be implemented in Cyclic Steam Stimulation (CSS) processes (which are more commonly referred to as the "huff and puff" method), where the same well is used for injection and production. According to this method, steam is injected into the well for several weeks then the heated oil is extracted (typically by pumping) and this cycle of heating followed by extracting is then repeated.
An aim of the present invention is to provide foaming compositions which are suitable for use for the enhanced recovery of crude oil, in particular in steam foam processes, especially for carrying out steam extraction (SAGD).
To this end, specific foaming compositions, proposed according to the present invention, are based on a mixture of specific surfactants, which the inventors have now demonstrated that it makes it possible:
- to form stable foams including at high temperatures, in particular above 150 C, preferably between 200 and 300 C, in particular between 200 and 250 C
(typically of the order of 220 C), which corresponds to the temperature range suitable, in particular, for steam extraction processes (SAGD).
3 - to induce a significant reduction in the interfacial tension (IFT) between the crude oil to be extracted and the water (in particular the water introduced, generally at least in part, the condensed water resulting from the steam, and the formation water naturally present in the underground formation from which the crude oil is to be extracted).
More specifically, according to a first aspect, the present invention relates to a composition C, suitable as a foaming composition, and usable in particular for SAGD
techniques, which comprises, in an aqueous medium M:
- at least one first anionic surfactant which is an alpha-olefin sulfonate (AOS); and - at least one second anionic surfactant which is an alkylarylsulphonate, preferably an alkylbenzene sulphonate (known as ABS).
The alpha-olefin sulfonates used in the compositions of the invention are typically C12 to C28 alpha-olefin sulfonates.
Moreover, in the alkylarylsulphonates used in the compositions of the invention, and in particular in the alkyl benzene sulphonates (ABS), the alkyl group preferably contains at least 12 carbon atoms, for example between 12 and 24.
According to an advantageous embodiment, in particular in the almost systematic case where the underground formation contains salts, composition C may advantageously also contain at least one third surfactant which is an alkyl glyceryl ether sulfonate (AGES) or an alkyl ether carboxylate.
The presence of AGES or an alkyl ether carboxylate proves, in particular, to be beneficial as regards the maintenance in solution of the surfactants of the compositions in the presence of salts. According to one embodiment, composition C comprises at least one additional AGES. According to another embodiment, compatible with the preceding one, composition C comprises at least one additional alkyl ether carboxylate.
When they are present, the AGES may, for example, be compounds as obtained according to the methods disclosed in US 3,024,273 or US 2,989,547.
The AGES that can be used according to the present invention preferably correspond to the following general formula (I):
More specifically, according to a first aspect, the present invention relates to a composition C, suitable as a foaming composition, and usable in particular for SAGD
techniques, which comprises, in an aqueous medium M:
- at least one first anionic surfactant which is an alpha-olefin sulfonate (AOS); and - at least one second anionic surfactant which is an alkylarylsulphonate, preferably an alkylbenzene sulphonate (known as ABS).
The alpha-olefin sulfonates used in the compositions of the invention are typically C12 to C28 alpha-olefin sulfonates.
Moreover, in the alkylarylsulphonates used in the compositions of the invention, and in particular in the alkyl benzene sulphonates (ABS), the alkyl group preferably contains at least 12 carbon atoms, for example between 12 and 24.
According to an advantageous embodiment, in particular in the almost systematic case where the underground formation contains salts, composition C may advantageously also contain at least one third surfactant which is an alkyl glyceryl ether sulfonate (AGES) or an alkyl ether carboxylate.
The presence of AGES or an alkyl ether carboxylate proves, in particular, to be beneficial as regards the maintenance in solution of the surfactants of the compositions in the presence of salts. According to one embodiment, composition C comprises at least one additional AGES. According to another embodiment, compatible with the preceding one, composition C comprises at least one additional alkyl ether carboxylate.
When they are present, the AGES may, for example, be compounds as obtained according to the methods disclosed in US 3,024,273 or US 2,989,547.
The AGES that can be used according to the present invention preferably correspond to the following general formula (I):
4 R-0-1-CH2-Ca-CH3)43-14-CH2-CH2-0-11,-CH2CHODHYCH2S03Y (I) where:
- R represents a linear or branched alkyl or alkenyl chain typically having from 3 to 18 carbon atoms;
- n is a number, optionally zero, ranging from 0 to 15, preferably from 0 to 3;
- p is a preferably non-zero number ranging from 0 to 20, preferably from 5 to 15;
- Y is a cation preferably selected from the group consisting of sodium, potassium, ammonium, calcium and magnesium.
According to an advantageous embodiment according to the invention, p is between 0 and 3 (typically p=0) and n is greater than or equal to 5.
The particular foaming compositions of the invention make it possible to form stable foams, including at high temperature, in particular in the aforementioned ranges, which makes them particularly well suited for steam injection in the context of a SAGD type process.
The stability of the foam to which reference is made here can, in particular, be measured by the half-life of the foam formed by expansion of the foam by a gas (typically dinitrogen used as model gas), with or without the presence of hydrocarbons (typically dodecane used as a model hydrocarbon, or else a crude oil), this half-life being all the higher as the foam is stable.
This half-life time is typically measured by forming the foam in a cylindrical container where the height of foam formed above the liquid then reaches an initial height h, then allowing the foam to evolve, the half-life time corresponding to the time after which the height of the foam above the liquid changes from the value h to half of this value, i.e., h/2.
The compositions of the present invention have another advantage, namely they induce a significant decrease in the interfacial tension (IFT) between the hydrocarbons and the water. This property turns out to be most notably advantageous when the compositions C of the invention are used in a SAGD type process.
Indeed, the surfactants used for the formation of the steam foam end up in contact with the
- R represents a linear or branched alkyl or alkenyl chain typically having from 3 to 18 carbon atoms;
- n is a number, optionally zero, ranging from 0 to 15, preferably from 0 to 3;
- p is a preferably non-zero number ranging from 0 to 20, preferably from 5 to 15;
- Y is a cation preferably selected from the group consisting of sodium, potassium, ammonium, calcium and magnesium.
According to an advantageous embodiment according to the invention, p is between 0 and 3 (typically p=0) and n is greater than or equal to 5.
The particular foaming compositions of the invention make it possible to form stable foams, including at high temperature, in particular in the aforementioned ranges, which makes them particularly well suited for steam injection in the context of a SAGD type process.
The stability of the foam to which reference is made here can, in particular, be measured by the half-life of the foam formed by expansion of the foam by a gas (typically dinitrogen used as model gas), with or without the presence of hydrocarbons (typically dodecane used as a model hydrocarbon, or else a crude oil), this half-life being all the higher as the foam is stable.
This half-life time is typically measured by forming the foam in a cylindrical container where the height of foam formed above the liquid then reaches an initial height h, then allowing the foam to evolve, the half-life time corresponding to the time after which the height of the foam above the liquid changes from the value h to half of this value, i.e., h/2.
The compositions of the present invention have another advantage, namely they induce a significant decrease in the interfacial tension (IFT) between the hydrocarbons and the water. This property turns out to be most notably advantageous when the compositions C of the invention are used in a SAGD type process.
Indeed, the surfactants used for the formation of the steam foam end up in contact with the
5 crude oil to be extracted. The reduction in the IFT, which they provide at this point then allows an improvement in the extraction of oil in the form of a water/hydrocarbon mixture.
According to another aspect, the present invention relates to a method for enhanced oil recovery from a subterranean formation comprising the following steps:
- a composition C of the aforementioned type is injected into said subterranean formation, through at least one injection well, said composition being in the presence of a gas (CO2, nitrogen, water steam or hydrocarbon gas, and, more preferably, water steam) within the subterranean formation; then - a fluid conveying the oil leaving the underground formation is recovered, through at least one production well.
Most often, in the context of the process of the invention, composition C is used to form a high temperature foam, namely at a temperature above 150 C and which most often remains below 300 C, for example. example between 200 and 250 C.
The joint presence in the underground formation of composition C and a gas brought to high temperature (water steam most often, generally mixed with a non-condensable gas such as dinitrogen (preferably), CO2, or a hydrocarbon gas), capable of forming a foam, can be obtained according to various methods, including in particular:
- the prior formation of a foam by expansion of composition C by the gas and the injection of this foam into the subterranean formation; or - the joint injection of composition C, in non-foamed form, and a gas into the subterranean formation; or - the injection of composition C into the subterranean formation, followed by the injection of a gas which is then contacted with composition C into the subterranean formation; or - the injection of composition C into a subterranean formation previously containing a gas (for example, injected beforehand into the formation).
According to a particular embodiment, the method comprises: the joint injection of water steam, of non-condensable gas, and of composition C, initially in non-foamed form.
According to another aspect, the present invention relates to a method for enhanced oil recovery from a subterranean formation comprising the following steps:
- a composition C of the aforementioned type is injected into said subterranean formation, through at least one injection well, said composition being in the presence of a gas (CO2, nitrogen, water steam or hydrocarbon gas, and, more preferably, water steam) within the subterranean formation; then - a fluid conveying the oil leaving the underground formation is recovered, through at least one production well.
Most often, in the context of the process of the invention, composition C is used to form a high temperature foam, namely at a temperature above 150 C and which most often remains below 300 C, for example. example between 200 and 250 C.
The joint presence in the underground formation of composition C and a gas brought to high temperature (water steam most often, generally mixed with a non-condensable gas such as dinitrogen (preferably), CO2, or a hydrocarbon gas), capable of forming a foam, can be obtained according to various methods, including in particular:
- the prior formation of a foam by expansion of composition C by the gas and the injection of this foam into the subterranean formation; or - the joint injection of composition C, in non-foamed form, and a gas into the subterranean formation; or - the injection of composition C into the subterranean formation, followed by the injection of a gas which is then contacted with composition C into the subterranean formation; or - the injection of composition C into a subterranean formation previously containing a gas (for example, injected beforehand into the formation).
According to a particular embodiment, the method comprises: the joint injection of water steam, of non-condensable gas, and of composition C, initially in non-foamed form.
6 According to a particularly interesting embodiment, the method of the invention is a SAG D type method. Thus, according to a particular embodiment, the method of the invention comprises the following steps:
- the injection through at least one injection well (said injection well being preferably at least partially drilled horizontally) of water steam brought to a temperature greater than or equal to 150 C (typically between 200 and 250 C), a non-condensable gas in particular of the aforementioned type, and a composition C
of the aforementioned type, whereby obtaining, due to the rise in temperature, a fluidification of the oil near the injection well; then - the recovery, typically by pumping through at least one production well (preferably a well having a horizontal drilling zone located below all or part of the aforementioned horizontal part of the wellbore), of a fluid comprising at least part of the oil which was fluidized by the injection of water steam, water at least in part resulting from the condensation of the steam and, typically, at least part of the surfactants of composition C.
Different aspects and possible embodiments of the invention are described in more detail below.
Sulfonate-type surfactants A composition C according to the invention typically comprises (i) at least one surfactant of the AOS type (alpha-olefin sulfate); and (ii) at least one surfactant of the alkylaryl sulfonate type, which is preferably an ABS alkylbenzene sulfonate.
Preferably, a composition C useful according to the invention comprises a mixture of at least one AOS and at least one ABS, preferably having the preferential characteristics mentioned above in the present specification.
In a composition according to the invention, the total AOS content is preferably between 0.01% and 0.8% by mass in composition C (this concentration corresponding to the total sum of the AOS present in composition C, relative to the total mass of composition C).
Furthermore, in a composition according to the invention, the total content of alkylarylsulphonates (typically of ABS) is preferably between 0.01% and 0.8%
by
- the injection through at least one injection well (said injection well being preferably at least partially drilled horizontally) of water steam brought to a temperature greater than or equal to 150 C (typically between 200 and 250 C), a non-condensable gas in particular of the aforementioned type, and a composition C
of the aforementioned type, whereby obtaining, due to the rise in temperature, a fluidification of the oil near the injection well; then - the recovery, typically by pumping through at least one production well (preferably a well having a horizontal drilling zone located below all or part of the aforementioned horizontal part of the wellbore), of a fluid comprising at least part of the oil which was fluidized by the injection of water steam, water at least in part resulting from the condensation of the steam and, typically, at least part of the surfactants of composition C.
Different aspects and possible embodiments of the invention are described in more detail below.
Sulfonate-type surfactants A composition C according to the invention typically comprises (i) at least one surfactant of the AOS type (alpha-olefin sulfate); and (ii) at least one surfactant of the alkylaryl sulfonate type, which is preferably an ABS alkylbenzene sulfonate.
Preferably, a composition C useful according to the invention comprises a mixture of at least one AOS and at least one ABS, preferably having the preferential characteristics mentioned above in the present specification.
In a composition according to the invention, the total AOS content is preferably between 0.01% and 0.8% by mass in composition C (this concentration corresponding to the total sum of the AOS present in composition C, relative to the total mass of composition C).
Furthermore, in a composition according to the invention, the total content of alkylarylsulphonates (typically of ABS) is preferably between 0.01% and 0.8%
by
7 mass in composition C (this concentration corresponding, likewise, to the total sum of the ABS present in composition C, relative to the total mass of composition C).
It is also preferred that the total content of alpha-olefin sulfates and alkylaryl sulfonates (typically the total content of AOS and ABS) be between 0.03% and 1%
by mass in composition C (this concentration corresponding, here again, to the total sum of AOS and ABS present in composition C, relative to the total mass of composition C).
According to an advantageous embodiment, a composition C comprising the following components may be used:
- as alpha-olefin sulfonates: C20 to C28 AOS (AOS with so-called "long"
chains) - as alpha-olefin sulfonates: ABS where the alkyl chain is C12 to C18 (ABS
with so-called "short" chains) In this case, the AOS/ABS mass ratio is preferably between 50:50 and 80:20.
According to another advantageous embodiment, a composition C comprising the following components may be used:
- as AOS: C12 to C16 AOS, for example C14 to C16 (AOS with so-called "short"
chains) - as alkylarylsulphonates: ABS where the alkyl chain is C20 to C24 (ABS
with so-called "long" chains) In this case, the AOS/ABS mass ratio is preferably between 20:80 and 50:50.
When AGES are present in a composition C according to the invention, it is generally preferred that the total content of AGES be between 0.01% and 0.2%
by mass, for example between 0.05% and 0.15% by mass in composition C (this concentration corresponding, here again, to the total sum of AGES present in composition C, relative to the total mass of composition C). Furthermore, the AGES/(AOS +ABS) mass ratio is preferably between 10% and 25%.
When alkyl ether carboxylates are used, they are preferably in the same amounts as those mentioned above for AGES.
It is also preferred that the total content of alpha-olefin sulfates and alkylaryl sulfonates (typically the total content of AOS and ABS) be between 0.03% and 1%
by mass in composition C (this concentration corresponding, here again, to the total sum of AOS and ABS present in composition C, relative to the total mass of composition C).
According to an advantageous embodiment, a composition C comprising the following components may be used:
- as alpha-olefin sulfonates: C20 to C28 AOS (AOS with so-called "long"
chains) - as alpha-olefin sulfonates: ABS where the alkyl chain is C12 to C18 (ABS
with so-called "short" chains) In this case, the AOS/ABS mass ratio is preferably between 50:50 and 80:20.
According to another advantageous embodiment, a composition C comprising the following components may be used:
- as AOS: C12 to C16 AOS, for example C14 to C16 (AOS with so-called "short"
chains) - as alkylarylsulphonates: ABS where the alkyl chain is C20 to C24 (ABS
with so-called "long" chains) In this case, the AOS/ABS mass ratio is preferably between 20:80 and 50:50.
When AGES are present in a composition C according to the invention, it is generally preferred that the total content of AGES be between 0.01% and 0.2%
by mass, for example between 0.05% and 0.15% by mass in composition C (this concentration corresponding, here again, to the total sum of AGES present in composition C, relative to the total mass of composition C). Furthermore, the AGES/(AOS +ABS) mass ratio is preferably between 10% and 25%.
When alkyl ether carboxylates are used, they are preferably in the same amounts as those mentioned above for AGES.
8 In general, it is preferred that the total content of surfactants be between 0.05%
and 1% by mass, for example of the order of 0.5% by mass in composition C
(this concentration corresponding, here again, to the total sum of the surfactants present in composition C, relative to the total mass of composition C).
The examples given below illustrate non-limiting embodiments of the invention and some of their advantages.
EXAMPLE
By way of illustration, a composition (Cl) according to the invention was prepared comprising in a brine (water comprising salts with a total of dissolved salts TDS = lg/L):
- 0.38% of a C20-24 ABS; and - 0.17% of a C14-16 AOS; and - 0.09% of a C12 AGES comprising 15E0 the percentages above corresponding to the final content of active ingredients in the composition.
The stability of the foam obtained with composition (Cl) was measured by co-injecting nitrogen and water steam and by looking at the evolution of the foam over time. At 200 C, the half-life of the foam (corresponding to the time at the end of which the volume of foam formed decreases by half) was measured and found to be equal to 42 minutes. At a higher temperature, the half-life remains relatively long:
of the order of 15 minutes.
Furthermore, composition (Cl) induces a very low IFT interfacial tension: by way of illustration, composition (Cl) was tested in the presence of crude oil (according to the "spinning drop" method). At 35 C, the IFT values measured are between 0.03 mN/rn and 0.008 mN/rn depending on the crude oil used. At higher temperatures, this property is retained, with measured IFT values between 0.2 and 0.6 mN/nri.
Similar results were, for example, obtained with compositions (C2) and (C3)
and 1% by mass, for example of the order of 0.5% by mass in composition C
(this concentration corresponding, here again, to the total sum of the surfactants present in composition C, relative to the total mass of composition C).
The examples given below illustrate non-limiting embodiments of the invention and some of their advantages.
EXAMPLE
By way of illustration, a composition (Cl) according to the invention was prepared comprising in a brine (water comprising salts with a total of dissolved salts TDS = lg/L):
- 0.38% of a C20-24 ABS; and - 0.17% of a C14-16 AOS; and - 0.09% of a C12 AGES comprising 15E0 the percentages above corresponding to the final content of active ingredients in the composition.
The stability of the foam obtained with composition (Cl) was measured by co-injecting nitrogen and water steam and by looking at the evolution of the foam over time. At 200 C, the half-life of the foam (corresponding to the time at the end of which the volume of foam formed decreases by half) was measured and found to be equal to 42 minutes. At a higher temperature, the half-life remains relatively long:
of the order of 15 minutes.
Furthermore, composition (Cl) induces a very low IFT interfacial tension: by way of illustration, composition (Cl) was tested in the presence of crude oil (according to the "spinning drop" method). At 35 C, the IFT values measured are between 0.03 mN/rn and 0.008 mN/rn depending on the crude oil used. At higher temperatures, this property is retained, with measured IFT values between 0.2 and 0.6 mN/nri.
Similar results were, for example, obtained with compositions (C2) and (C3)
9 comprising respectively:
For (C2):
- 0.25% of an XOF-30A ABS; and - 0.17% of a Rhodacal A246L type AOS; and - 0.09% of a Rhodapex L15GS type AGES
- comprising respectively:
For (C3):
- 0.13% of a C18 ABS; and - 0.29% of a C20-28 AOS; and - 0.09% of a Rhodapex L15GS type AGES
For (C2):
- 0.25% of an XOF-30A ABS; and - 0.17% of a Rhodacal A246L type AOS; and - 0.09% of a Rhodapex L15GS type AGES
- comprising respectively:
For (C3):
- 0.13% of a C18 ABS; and - 0.29% of a C20-28 AOS; and - 0.09% of a Rhodapex L15GS type AGES
Claims (16)
1. A composition suitable as a foaming composition which comprises, in an aqueous medium M:
- at least a first anionic surfactant which is an alpha-olefin sulfonate (AOS); and - at least one second anionic surfactant which is an alkylarylsulphonate, preferably an alkylbenzene sulphonate (ABS).
- at least a first anionic surfactant which is an alpha-olefin sulfonate (AOS); and - at least one second anionic surfactant which is an alkylarylsulphonate, preferably an alkylbenzene sulphonate (ABS).
2. The composition according to claim 1, wherein the first anionic surfactant is a sulfonate of C12 to C28 alpha-olefins.
3. The composition according to claim 1 or 2, wherein the total content of alpha-olefin sulfonate (AOS) is between 0.01% and 0.8% by weight in composition C.
4. The composition according to any of claims 1 to 3, where the second anionic surfactant is an alkylarylsulphonate, for example, an alkylbenzene sulphonate, which preferably comprises at least 12 carbon atoms, for example, between 12 and 24.
5. The composition according to any of claims 1 to 4, wherein the total content of alkylaryl sulphonates (typically ABS) is between 0.01% and 0.8% by mass in composition C.
6. The composition according to any of claims 1 to 5, wherein the total content of alpha-olefin sulphates and alkylaryl sulfonates (typically, the total content of AOS
and ABS) is between 0.03% and 1% by mass in composition C.
and ABS) is between 0.03% and 1% by mass in composition C.
7. The composition according to any of claims 1 to 6, which further contains at least one third surfactant which is an alkyl glyceryl ether sulfonate (AGES) or an alkyl ether carboxylate.
8. The composition according to claim 7, wherein said third surfactant is an alkyl glyceryl ether sulfonate, preferably corresponding to the general formula (I) below:
R-0-1-C1-12-CH(-CH4-0-1-14-CH2-CH2-03-CH2CH(OH)-CH2-SOX (I) , õ..
where:
- R represents a linear or branched alkyl or alkenyl chain - n is a number, optionally zero, ranging from 0 to 15 - p is a preferably non-zero number ranging from 0 to 20 - Y is a cation preferably selected from the group consisting of sodium, potassium, ammonium, calcium and magnesium.
R-0-1-C1-12-CH(-CH4-0-1-14-CH2-CH2-03-CH2CH(OH)-CH2-SOX (I) , õ..
where:
- R represents a linear or branched alkyl or alkenyl chain - n is a number, optionally zero, ranging from 0 to 15 - p is a preferably non-zero number ranging from 0 to 20 - Y is a cation preferably selected from the group consisting of sodium, potassium, ammonium, calcium and magnesium.
9. The composition according to claim 8, where:
p is between 0 and 3, p preferably being zero; and n is greater than or equal to 5.
p is between 0 and 3, p preferably being zero; and n is greater than or equal to 5.
10. The composition according to any of claims 7 to 9, where the total AGES
content is between 0.01% and 0.2% by mass in composition C, with an AGES/(A0S+ABS) weight ratio preferably between 10% and 25%.
content is between 0.01% and 0.2% by mass in composition C, with an AGES/(A0S+ABS) weight ratio preferably between 10% and 25%.
11. The composition according to any of claims 1 to 10, where the total content of surfactants is between 0.05% and 1% by mass in composition C.
12. The composition according to any of claims 1 to 11, comprising:
- as alpha-olefin sulfonates: C20 to C28 AOS
- as alpha-olefin sulfonates: ABS where the alkyl chain is C12 to C18, with an AOS/ABS mass ratio preferably between 50:50 and 80:20.
- as alpha-olefin sulfonates: C20 to C28 AOS
- as alpha-olefin sulfonates: ABS where the alkyl chain is C12 to C18, with an AOS/ABS mass ratio preferably between 50:50 and 80:20.
13. The composition according to any of claims 1 to 11, comprising:
- as alpha-olefin sulfonates: C12 to C16 AOS
- as alpha-olefin sulfonates: ABS, where the alkyl chain is C20 to C24 with an AOS/ABS mass ratio preferably between 20:80 and 50:50.
- as alpha-olefin sulfonates: C12 to C16 AOS
- as alpha-olefin sulfonates: ABS, where the alkyl chain is C20 to C24 with an AOS/ABS mass ratio preferably between 20:80 and 50:50.
14. A method of enhanced oil recovery from a subterranean formation comprising the following steps:
- injecting the composition as defined in one of claims 1 to 13 in said subterranean formation through at least one injection well, said composition being in the presence of a gas within the subterranean formation; then - recovering, through at least one production well, a fluid conveying the oil exiting the subterranean formation.
- injecting the composition as defined in one of claims 1 to 13 in said subterranean formation through at least one injection well, said composition being in the presence of a gas within the subterranean formation; then - recovering, through at least one production well, a fluid conveying the oil exiting the subterranean formation.
15. The method according to claim 14, wherein the composition is used to form a foam at a temperature above 150 C.
16. The method according to claim 14 or 15 comprising the following steps:
- injecting, through at least one injection well, water steam brought to a temperature greater than or equal to 150 C, typically between 200 and 250 C, a non-condensable gas such as dinitrogen, and a composition, such as defined in one of claims 1 to 13, thus obtaining, due to the rise in temperature, fluidization of the oil near the injection well; then - recovering, typically by pumping through at least one production well, a fluid comprising at least part of the oil which was fluidized by the steam injection, water at least in part formed from the condensation of the steam and, typically, at least a portion of the surfactants of the composition.
- injecting, through at least one injection well, water steam brought to a temperature greater than or equal to 150 C, typically between 200 and 250 C, a non-condensable gas such as dinitrogen, and a composition, such as defined in one of claims 1 to 13, thus obtaining, due to the rise in temperature, fluidization of the oil near the injection well; then - recovering, typically by pumping through at least one production well, a fluid comprising at least part of the oil which was fluidized by the steam injection, water at least in part formed from the condensation of the steam and, typically, at least a portion of the surfactants of the composition.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| EP19190051.3 | 2019-08-05 | ||
| EP19190051 | 2019-08-05 | ||
| PCT/EP2020/071575 WO2021023633A1 (en) | 2019-08-05 | 2020-07-30 | Foaming formulations for enhanced oil recovery |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA3145266A1 true CA3145266A1 (en) | 2021-02-11 |
Family
ID=67544136
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA3145266A Pending CA3145266A1 (en) | 2019-08-05 | 2020-07-30 | Foaming formulation comprising sulphonates for oil recovery |
Country Status (4)
| Country | Link |
|---|---|
| CN (1) | CN114555754A (en) |
| CA (1) | CA3145266A1 (en) |
| CO (1) | CO2022001378A2 (en) |
| WO (1) | WO2021023633A1 (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US11950595B2 (en) | 2017-09-26 | 2024-04-09 | Ecolab Usa Inc. | Acid/anionic antimicrobial and virucidal compositions and uses thereof |
Family Cites Families (13)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US2989547A (en) | 1956-12-10 | 1961-06-20 | Procter & Gamble | Method for preparing detergent compositions |
| DE1249434B (en) | 1957-05-14 | 1968-03-28 | The Procter S. Gamble Company, Cincinnati, Ohio (V. St. A.) | laundry detergent |
| GB8331733D0 (en) * | 1983-11-28 | 1984-01-04 | Shell Int Research | Olefin sulphonate compositions |
| US4643256A (en) * | 1985-03-18 | 1987-02-17 | Shell Oil Company | Steam-foaming surfactant mixtures which are tolerant of divalent ions |
| GB2205122B (en) * | 1987-05-28 | 1991-09-11 | Chevron Res | Steam or gas enhanced oil recovery method |
| US5273682A (en) * | 1989-09-22 | 1993-12-28 | Chevron Research And Technology Company | Viscosity control additives for foaming mixtures |
| US5000262A (en) * | 1989-09-22 | 1991-03-19 | Mitchell Danzik | Viscosity control additives for foaming mixtures |
| CA2044473C (en) * | 1991-06-13 | 2002-09-17 | Tapantosh Chakrabarty | Sweep in thermal eor using emulsions |
| CN102676145B (en) * | 2012-05-16 | 2014-06-04 | 中国石油天然气股份有限公司 | High-temperature foaming agent and preparation method thereof |
| WO2014055213A2 (en) * | 2012-10-01 | 2014-04-10 | Huntsman Petrochemical Llc | Surfactant formulation for release of underground fossil fluids |
| US20140174735A1 (en) * | 2012-12-26 | 2014-06-26 | Shell Oil Company | Method, system, and composition for producing oil |
| CA2957759C (en) * | 2014-08-22 | 2022-08-30 | Stepan Company | Steam foam methods for steam-assisted gravity drainage |
| FR3065884B1 (en) * | 2017-05-05 | 2019-04-19 | Rhodia Operations | ULTRASONIC SURFACE SOLUTION OF SURFACTANTS FOR ASSISTED OIL RECOVERY |
-
2020
- 2020-07-30 WO PCT/EP2020/071575 patent/WO2021023633A1/en active Application Filing
- 2020-07-30 CA CA3145266A patent/CA3145266A1/en active Pending
- 2020-07-30 CN CN202080055096.5A patent/CN114555754A/en active Pending
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- 2022-02-10 CO CONC2022/0001378A patent/CO2022001378A2/en unknown
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US11950595B2 (en) | 2017-09-26 | 2024-04-09 | Ecolab Usa Inc. | Acid/anionic antimicrobial and virucidal compositions and uses thereof |
Also Published As
| Publication number | Publication date |
|---|---|
| WO2021023633A1 (en) | 2021-02-11 |
| CO2022001378A2 (en) | 2022-05-31 |
| CN114555754A (en) | 2022-05-27 |
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