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    • 专利摘要:
    applications and methods of improved foam stability. a method for improving foam stability in foaming compositions for use in oilfield treatment applications, including but not limited to use in mobility control for gas flooding. the method comprises the step of adding to a foaming composition a foam stabilizer of formula (i): wherein r1 is an alkyl starch group or a linear or branched alkyl group, r2 and r3 are individually hydrogen or a methyl group, r4, r5 and r6 are individually hydrogen or a hydroxy group, with the proviso that at least one of the groups r4, r5 or r6 is a hydroxyl group, in which the alkyl group has more than about 10 carbon atoms. also disclosed are methods for improving foam stability in an aqueous foaming composition, which comprises the step of adding a foam stabilizer selected from alkyl dimethyl betaine, alkyl amidopropyl hydroxy sulfobetaine or alkyl hydroxy sulfobetaine, where the alkyl group has more than 10 carbon atoms, or 12 carbon atoms, or 16 carbon atoms.
    公开号:BR112013029345B1
    申请号:R112013029345-4
    申请日:2012-05-11
    公开日:2021-02-23
    发明作者:Mikel Morvan；Max Chabert；Manilal S. Dahanayake
    申请人:IFP Energies Nouvelles；
    IPC主号:
    专利说明:

    FIELD OF THE INVENTION
    This invention relates to the use of foam stabilizers in aqueous systems and, more particularly, the use of foam stabilizers to reinforce mobility control during oil recovery operations. BACKGROUND OF THE INVENTION
    Fractured reservoirs containing oil generally consist of two distinct elements: the fracture network and a matrix (for example, a micro porous matrix). The fracture network is a series of interconnected cracks that can easily transmit fluids (very high permeability), but make up only a small fraction of the total porosity. The matrix portion consists of porous petroleum rock that typically exhibits much lower permeability than the fracture network, but has most of the total pore volume in the reservoir. Hydrocarbon production is usually less efficient in fractured reservoirs. During primary production, the pressures of the natural reservoir to produce the oil at the site decrease rapidly, leaving about more than 90% of the original oil left in place, trapped in most of the matrix (including, for example, micro porous mesh) . Similarly, conventional secondary recovery methods do not displace substantial volumes of oil "left in place".
    Conventional water flooding techniques have relatively low efficiency in highly fractured reservoirs. Flooding with water in these reservoirs is characterized by the advance of water in the beginning and rapidly increasing oil-water proportions to an unprofitable level. The injected water tends to travel only through the fractures and does not interact with the oil trapped in the matrix rock (for example, micro porous). The injected water cannot penetrate the matrix and, thus, displace and recover the oil trapped in the porous matrix. The injected water tends to recover only the oil left behind in the fracture system after primary production. The limited or non-existent interaction of the water injected with the oil retained in the matrix is also caused, in part, by the matrix portion not being wetted with water.
    The matrix will not absorb or take spontaneously in water. This is largely due to the tendency of water mobility in areas of high permeability, and not in areas of low permeability (which has most of the oil retained).
    One approach to increase the penetration of a water phase with the trapped oil matrix zones has been to add a surfactant to the water to modify the wettability of carbonate from wet oil to wet water. Previous research and field experience has shown that adding a low concentration of the properly selected surfactant to water will reduce interfacial tension and also now create a wet condition in the area near the fracture face. With this altered condition, the aqueous phase then penetrates a certain distance in the porous matrix and, thus, pushes out some of the oil that was inside the pores. In this countercurrent imbibition process, the oil that is displaced from the matrix then moves to the fracture system. Once pushed into the fracture system, the oil can be moved easily to a production well. In a countercurrent soaking process, with or without the addition of a water-wetting surfactant, the oil recovery rate is dependent on the capillary pressure characteristics of the porous stone matrix. That is, the imbibition process is essentially unaffected by conventional techniques for controlling field operations, such as the selection of pressures and flow rates.
    Techniques for using surfactants to recover oil in the formation of carbonate are disclosed by G. Hirasaki and D. L Zhang in "Surface Chemistry of Oil Recovery from Fractured, Oil-Wet Carbonate Formations" (2000); by Austad and Standes in "Spontaneous Imbibition of Water onto Oil-Wet Carbonates", Journal of Petroleum Science and Engineering, vol. 39, pages 363-376, (2003); by W.W. Weiss in "Artificail Intelligence Used to Evaluate 23 Single-Well Surfactant Soak Treatments", SPE Reservoir Evaluation & Engineering, June 2006; U.S. Patent No. 2,792,894; 4,364,431; 4,842,065; 5,247,993 and U.S. Patent Application No. 2007/0215347 A1.
    Another approach is to use flooding techniques such as gas, air, CO2, flooding of natural gas, or any combination thereof, which is a form of advanced oil recovery (EOR). Generally, EOR with CO2 is where the CO2 gas is pumped / injected into an injection or production well for an underground formation (for example, fracture reservoir) and, under certain physical conditions, mixes miscibly with retained oil or left in place. This allows the oil left in place to be more easily moved into the areas of high permeability and recovered. CO2, the high pressure and temperature of the reservoir, mixes miscibly with the oil to form a low viscosity fluid that can be more easily mobilized. In addition, CO2 has the ability to invade areas previously not invaded by water, as well as to release and reduce trapped oil. The mixed waste oil and gas can also be replaced by a chase phase, for example, with water in a WAG process (water alternating gas).
    Floods of nitrogen and flue gases (non-hydrocarbon gases) can also be used. Nitrogen, however, has a low viscosity, with poor miscibility with oil, and requires a much higher pressure to generate or develop miscibility, compared to the CO2 flood: As such, floods of nitrogen and flue gas are generally used as a "carrier gas" in a miscible flood in hydrocarbon and CO2 gas (ie nitrogen or other low-cost gases, being used to supply a gas unit in which a significant portion of the reservoir volume is filled with such gas (s)). However, while nitrogen can be used as carrier gas, it is understood that nitrogen and / or flue gas can be used in any gas flooding technique described here.
    As explained above, a fractured reservoir is extremely heterogeneous and has areas of high permeability in the vicinity of areas of low permeability. Thus, CO2 and similar gas flooding techniques - analogous to some water flooding techniques - suffer from the tendency for the injected gas to sweep the oil from only a limited area of the reservoir, that is, from areas of high permeability. This is partly because the viscosity of CO2 under reservoir conditions is much lower than that of most oils, which limits the sweeping efficiency of displacement and, therefore, oil recovery.
    Thus, an approach to increase the penetration of a gas into the matrix blocks containing retained oil was to inject foam under pressure into the petroleum formation. The foam is usually formed by aerating a mixture of surfactant and water. Foams having high apparent and increased viscosity will reduce the mobility of water / surfactant solutions for large fractures or areas of high permeability by effectively closing them and / or providing a barrier to entry. With the condition changed, a subsequently introduced gas (such as CO2, natural gas) is bypassed and / or capable of penetrating the low permeability porous matrix. In some special embodiments, the reservoir is a non-fractured reservoir, but an oil reservoir containing naturally occurring areas of high permeability and naturally occurring areas of low permeability.
    A problem with the use of gas mobility control foams, however, is the inherently short life of the foams. For example, in oil field applications, foams dissipate relatively quickly, decreasing the effectiveness of blocking high, highly permeable high fractures and any improvement in oil recovery. It would be desirable to have a method for increasing foam stability in aqueous applications, such as in applications for oil fields. SUMMARY OF THE INVENTION
    It has been found that the use of foam stabilizers and / or surfactants described here significantly improves performance in oilfield treatment fluids or applications, in particular, in controlling flood gas mobility.
    The problem of foam stability in some cases has been directed to the use of both natural and synthetic polymers; but the use of such polymers faces drawbacks. For example, due to their high molecular weights, these polymers are difficult to formulate in surfactant formulations. Its poor hydration and dispersion capacity, incompatibility of polymers (namely, cationic) with anionic surfactants used frequently, high sensitivity to concentration versus foam performance contributes to the difficulty in using these polymers as additives in improving foaming in aqueous solutions of foam. Even when ideally formulated, these polymers are still limited by foam expansion, mainly due to their low diffusion rates for the foam creation interfaces.
    In one aspect, a method for increasing oil recovery from an oil formation within a reservoir is described herein, comprising: (a) introducing a foaming composition under pressure into the oil formation, (b) introducing a gas under pressure in the oil formation, in which the presence of the foaming composition affects the gas flow inside the oil formation and (c) extraction of oil through a well into the reservoir. The foaming composition may comprise a foam stabilizer. The foam stabilizer can be alkyl dimethyl betaine, alkyl amidopropyl hydroxy sulfobetaine or alkyl hydroxy sulfobetaine or any combination thereof, where the alkyl group has more than 10 carbon atoms, or 12 carbon atoms, or in another embodiment, of 16 carbon atoms. In other embodiments, the foaming composition may optionally comprise a foaming gas. In other embodiments, the foaming composition may comprise water. In other embodiments, the foaming composition may comprise any one or a combination selected from a foaming gas, water or one or more additional surfactants or surfactants. In some embodiments, the components of the foaming composition are mixed before being introduced into the reservoir or formation of oil formation. In other embodiments, one or more components of the foaming composition are injected into the oil formation at different times (for example, sequentially) and thus become mixed at the bottom of the well.
    In another aspect, methods for increasing oil recovery from an oil formation within a reservoir are described herein, comprising: (a) introducing a foaming composition under pressure into the oil formation, (b) introducing a gas under pressure into the formation oil, in which the presence of the foaming composition affects the gas flow within the oil formation and (c) extraction of oil through a well into the reservoir, where the foaming composition comprises a foam stabilizer that has the formula (I):
    where R1 is an alkylamido group or a linear or branched group, R2 and R3 are individually hydrogen, a methyl group or a hydroxyethyl group, R4, R5 and R6 are individually hydrogen or a hydroxy group, with the proviso that at least one of R4, R5 or R6 represents a hydroxyl group, where the alkyl group has more than about 10 carbon atoms. In one embodiment, the alkyl group has more than about 11, 12 or 13 carbon atoms. In another embodiment, the alkyl group has more than about 14 or 16 carbon atoms.
    In one embodiment, the alkyl starch group has the formula (II):
    where R7 represents a linear or branched group having more than about 10 carbon atoms, where n is an integer from 2 to 5. In one embodiment, "n" is an integer from 3, and in another embodiment of "n" is an integer of 4.
    In one embodiment, the foam stabilizer is of formula (III):
    where R1 is an alkyl starch group or a linear or branched group, R3 and R4 are individually hydrogen or a methyl group, where the alkyl group has more than about 12 carbon atoms. The gas is chosen from carbon dioxide, air, nitrogen, water vapor, flue gas or any combination thereof. In some embodiments, the introduction of the foaming composition into an oil formation means that some of the foaming composition is introduced or placed in one or more high permeability zones located within the oil formation. In one embodiment, the step of introducing the gas into the oil formation includes diverting or flowing the gas into one or more zones of low permeability located within the oil formation, while the foaming composition placed (or introduced) in one or more zones of oil high permeability prevents gas from entering such an area. This, in turn, can force the gas into one or more zones of low permeability.
    In yet another aspect, methods for increasing foam stability in an aqueous foaming composition are described herein, comprising the step of adding to that foaming composition a foam stabilizer of formula (I):
    where R1 is an alkylamido group or a branched or linear group, R2 and R3 are individually hydrogen or a methyl group, R4, R5 and R6 are individually hydrogen or a hydroxy group, with the proviso that at least one of R4 , 5 R5 or R6 represents a hydroxyl group, where the alkyl group has more than about 10 carbon atoms. The alkylamido group can be of formula (II) (above), where R7 represents a linear or branched alkyl group having more than about 10 carbon atoms, where "n" is an integer from 2 to 5.
    In one embodiment, the foam stabilizer is of formula (III):
    where R1 is an alkyl starch group or a linear or branched group, R2 and R3 are individually hydrogen or a methyl group, where the alkyl group has more than about 20-12 carbon atoms.
    In yet another aspect, methods for increasing foam stability in aqueous foaming compositions are described herein, the step of adding to a foaming composition a foam stabilizer selected from alkyl dimethyl betaine, alkyl amidopropyl hydroxy sulfobetaine, alkyl hydroxy sulfobetaine or any combination of these, where the alkyl group has more than 10 carbon atoms. The aqueous foaming composition may be part of an oil field treatment fluid.
    Foam stabilizers or surfactants that are found to increase foam, foam expansion rate and foam stability within a broader range of concentrations are described herein, as well as conferring other benefits to aqueous formulations. Due to much lower molecular weights compared to the polymers traditionally used, the surfactants described here are easily incorporated into foaming solutions. In one embodiment, certain zwitterionic / amphoteric surfactants are compatible with (foaming) anionic surfactants used in most formulations used for the generation of foams. DETAILED DESCRIPTION OF THE DISCLOSURE
    As used herein, the term "alkyl" means a saturated straight-chain or branched hydrocarbon monovalent group, typically a monovalent (C1-C20) hydrocarbon radical, such as, for example, saturated, methyl, ethyl, n-propyl, iso-propyl, n-butyl, sec-butyl, t-butyl, pentyl, or n-hexyl, which can optionally be substituted on one or more of the carbon atoms of the radical. In one embodiment, an alkyl radical is substituted on one or more carbon atoms of the radical with hydroxy, alkoxy, amino, halo, carboxy, or phosphono, such as, for example, hydroxymethyl, hydroxyethyl, methoxymethyl, ethoxymethyl, isopropoxyethyl, aminomethyl, chloromethyl or trichloromethyl, carboxyethyl, or phosphonomethyl. The term "alkyl" can also mean an unsaturated linear chain, branched chain, or cyclic hydrocarbon radical, which contains one or more carbon-carbon double bonds, such as, for example, ethenyl, 1-propenyl, or 2-propenyl, which it can optionally be substituted on one or more of the carbon atoms of the radical.
    As used herein, the term "alkoxy" means an oxy radical that is substituted with an alkyl group, such as, for example, methoxy, ethoxy, propoxy, isopropoxy, or butoxy, which can optionally be further substituted by or more carbon atoms of the radical.
    As used herein, the term "cycloalkyl" means a saturated cyclic hydrocarbon radical, typically a group (C1-C18), saturated cyclic hydrocarbon radical, such as, for example, cyclohexyl or cyclooctyl, which can optionally be replaced by one or more of the carbon atoms of the radical.
    As used herein, the term "aryl" means a monovalent unsaturated hydrocarbon containing one or more six-membered carbon rings, where unsaturation can be represented by three conjugated double bonds, such as, for example, phenyl, naphthyl, anthryl , phenanthryl, or biphenyl, which can optionally be substituted on one or more of the ring's carbon atoms. In one embodiment, an aryl radical is a substituent of one or more carbon atoms of the radical with hydroxy, alkyl, halo, haloalkyl, or amino, such as, for example, methylphenyl, dimethylphenyl, hydroxyphenyl, chlorophenyl, trichloromethylphenyl, or aminophenyl .
    As used herein, the term "aralkyl" means an alkyl group substituted with one or more aryl groups, such as, for example, phenylmethyl, phenylethyl, or triphenylmethyl, which can optionally be further substituted by one or more of the atoms carbon of the radical.
    As used herein, the term "alkaryl" means an aryl group substituted with one or more alkyl groups, such as, for example, methylphenyl, dimethylphenyl, or trimethylphenyl, which can optionally be further substituted by one or more of the atoms carbon of the radical.
    As used herein, the indication that a radical may be "optionally substituted" or "optionally still substituted" means, in general, that unless still limited, either explicitly or by the context of such reference, that such radicals may be substituted with one or more organic or inorganic substituent groups, such as, for example, alkyl, aryl, aralkyl, alkaryl, a heteroatom, or heterocyclyl, or with one or more functional groups that are capable of coordination with metal ions, such as hydroxyl, carbonyl, carboxyl, amino, imino, starch, phosphonic acid, sulfonic acid, or arsenate, or organic and inorganic esters thereof, such as, for example, sulfate or phosphate, or their salts.
    As used herein, the term "(Cx-Cy)", in reference to an organic group, where x and y are each integers, indicates that the group may contain from x carbon atoms to y carbon atoms per group.
    As used herein, the term "mobility control" is to be interpreted in its broadest sense and is also intended to include a process in which the sweeping efficiency of a reservoir or oil formation is improved.
    In one aspect, methods for improving foam stability in an aqueous foaming composition are described herein, comprising the step of adding a foam stabilizer to the aqueous foaming composition. In one aspect, methods for increasing oil recovery from an oil formation from within a reservoir are described herein, which comprises introducing a foaming composition into an oil formation; introduction of a gas under pressure in the oil formation; and extraction of oil through a well in the reservoir, in which the foaming composition introduced in the oil formation affects or diverts the gas flow to the areas of low permeability of the oil formation. In one embodiment, the use of the foaming compositions described herein is used as a mobility control.
    In one embodiment, the foaming composition consists of water and a foam stabilizer, as described herein. In another embodiment, the foaming composition comprises water and a foaming gas. The foaming gas can be any gas that gives foaming properties to the foaming composition, such as nitrogen, air, carbon dioxide, steam, natural gas or any combination thereof. It is understood that the foaming composition may comprise other components, including, for example, one or more surfactants. Surfactants are typically one or more nonionic surfactants, one or more cationic surfactants, one or more amphoteric surfactants, one or more zwitterionic surfactants, one or more anionic surfactants or any combination thereof. In a particular embodiment, the foaming composition consists of the foam stabilizer, water and at least one anionic surfactant used as a foaming agent. In one embodiment, the anionic surfactant is a sulfonated alkyl olefin.
    In one embodiment, the foaming composition may be or be part of any industrial foam or used commercially, including, but not limited to, fire fighting foams, foam cleaning products, industrial foams, agricultural foams, foams used in home and personal care products.
    In another aspect, methods for improving oil recovery from an oil formation using a foam stabilizer are described herein. In one embodiment, the foam stabilizer described herein increases the foam stability of an oil well treatment fluid. In another embodiment, the foam stabilizer described herein increases the foam stability of a foaming composition, which foaming composition can be used as part of an oil well treatment fluid. The foaming composition can also be used in conjunction with an oil well treatment fluid in a multi-step process to recover oil from a formation.
    The foam stabilizer can be part of a package (for example, surfactant package) introduced into the formation, either alone or with another fluid composition, or fluids, for example, the foaming composition or well treatment fluid of oil.
    In one embodiment, processes are described herein to improve the recovery of oil from an oil formation comprising the step of adding to the aqueous foaming composition or oil well treatment fluid (or both) a foam stabilizer. In the foam stabilizer it is of formula (I):
    R1 can be an alkyl starch group in one embodiment. In another embodiment, R1 comprises a branched or linear alkyl group. Typically, the branched or linear alkyl group is a carbon group of greater than about 8, more typically greater than about 10, even more typically greater than 12, and more typically greater than 16. In other forms of In this embodiment, the branched or linear alkyl group is a carbon group greater than 13 or greater than 14.
    In one embodiment, the straight or branched alkyl group is a C10-C24 alkyl group, in another embodiment, a C12-C22 alkyl group, in yet another embodiment, a C14-C22 alkyl group, and in yet another embodiment, a C16-C18 alkyl group. R2 and R3 are individually hydrogens, a methyl group or a hydroxyethyl group. In one embodiment, R2 and R3 are both methyl groups. R4, R5 and R6 are individually hydrogen or a hydroxy group, with the proviso that at least one of R4, R5 or R6 is a hydroxyl group. In a particular embodiment, R5 represents a hydroxyl group, and R4 and R6 are both hydrogen. In such a particular embodiment, the structure has the formula (III):
    wherein R1, R2 and R3 are the same as indicated above.
    In one embodiment, the alkyl starch group has the formula (II):
    wherein R7 represents a straight or branched alkyl group having more than about 10 carbon atoms. The linear or branched alkyl group may have a carbon group greater than about 12, or in another embodiment a carbon group greater than about 13, or greater than 14, or greater than 15. In other forms embodiment, the branched or linear alkyl group, is a carbon group greater than 16 or greater than 20. In one embodiment, the linear or branched alkyl group is a C10-C alkyl group, in another form of embodiment, a C12-C22 alkyl group, in yet another embodiment, a C14-C22 alkyl group, and in yet another embodiment, a C16-C18 alkyl group.
    "N" can be any integer between about 1 and 15, more typically an integer between about 2 to about 10. In one embodiment, "n" is an integer between 3 to about 5. In another embodiment "n" is an integer between about 2 and about 4. In one embodiment, "n" is an integer of 3, and in another embodiment "n "is an integer of 4.
    In one embodiment, the treatment fluid is a foaming composition, wherein the foaming composition may comprise a foaming component, water and a foam stabilizer described herein. In another embodiment, the foaming composition comprises a foaming and water component, wherein the foaming component is the foam stabilizer described herein. In yet another embodiment, the foaming composition comprises a foam stabilizer, one or more surfactants used as foaming agents, optionally, a gas, optionally, one or more surfactants, and optionally, water.
    In a method of the present disclosure, a foaming composition that has a component part of one or more foam stabilizers described herein is introduced, for example, injected, into a reservoir or formation at high pressure for the purpose of pushing or expelling the oil from this. The foaming composition, which takes on a foam-like shape or consistency, enters and settles within the large fractures within the formation (ie, areas of high permeability) and substantially diverts one or more gases, or a gas / surfactant mixture or a gas / aqueous fluid mixture in the less permeable oil support matrix (ie, areas of low permeability). This, in turn, can mobilize the retained oil and / or gas from the matrix through the fracture network. Essentially, the foam composition acts as a barrier to entry into the fracture network. When the fracture network is effective or substantially bonded, the gas penetrates the porous forming matrix instead of the fracture network. The gas pushes the oil retained in the matrix to the fracture network, where it can be easily recovered by conventional means.
    In one embodiment, in addition to one or more foam stabilizers or one or more foaming agents, surfactants or other polymers can be present in the foaming composition described herein. Surfactants can act to reduce IFT between the treatment fluid and oil retained in the formation matrix and / or increase the viscosity of the injected water during treatment.
    In some embodiments, the gas used in the gas flooding operation described herein is a gas or a combination of gases and aqueous fluids. The fluid may be in a supercritical state. The gas or gas / liquid mixture can be injected in the form of a bullet or a continuous injection. In some embodiments, a gas injection is used in conjunction with a water injection, in a water-alternating-gas (WAG) process.
    As used herein, the term "reservoir" is inclusive of the term "petroleum formation" (including but not limited to a petroleum carbonate formation) as such a formation is normally located within a reservoir. One or more wells can be located in the vicinity of the reservoir and / or the one in order to extract the oil. The treatment fluid can be introduced through the well or other protrusion, hole or opening into the reservoir. The treatment fluid will be introduced at a pressure high enough to ensure substantial infiltration of the treatment fluid into the fracture network of the formation and substantial exposure of the porous matrix of such formation. The oil can be extracted, at the same or a different location from the point where the treatment fluid is introduced.
    In some embodiments, the surfactants are present in the treatment fluid in an amount sufficient to supply the treatment fluid (before injection into the formation or reservoir) with a crude oil surface tension (IFT) of roughly about 10 mNm or less, preferably about 1 mNm or less, and more preferably about 0.1 or less. The surfactants are preferably present in the treatment liquid in an amount of about 0.1 to about 10% by weight and more preferably about 0.5 to about 6% by weight based on the total weight of the treatment fluid. treatment. The amount of surfactant required will vary considerably depending on factors, including the type of surfactant, brine content in the fluid, and impurities in the treatment fluid. Surfactants are effective in providing the desired levels of IFT, even in treatment fluids with high salinity, that is, up to about 9 Kg / l (20 lbs / gallon) of concentration. Salts can be inorganic or organic salts, including monovalent, divalent, and trivalent species. Inorganic salts commonly found in brackish and salt water include, but are not limited to, potassium chloride and bromide salts, sodium, calcium, magnesium, zinc, iron, and ammonium.
    Foaming agents of interest may include, but are not limited to, nonionic surfactants, cationic surfactants, amphoteric surfactants, zwitterionic surfactants and anionic surfactants. Non-ionic surfactants that do not contain a charged portion. Amphoteric surfactants both have a positively charged unit and a negatively charged part over a certain pH range (for example, typically slightly acidic), only a negatively charged part over a certain pH range (for example, typically slightly alkaline), and only a positively charged portion at a different pH range (for example, typically moderately acidic). Zwiterionic surfactants have a permanently charged portion positively in the pH-independent molecule, and a permanently charged portion negatively at alkaline pH. Cationic surfactants have a permanently positively charged portion in the molecule, regardless of pH. Anionic surfactants have a permanently negatively charged portion, except at very acidic pH. It is understood, however, that any surfactant or composition that can form a moderate to strong foam is useful in the compositions and methods described herein.
    In one embodiment, the foaming agent must be present in the foaming compositions described herein, in an amount sufficient to provide a suitable foam. In some embodiments, the foaming agent is present in an amount in the range of about 0.1% and about 15% by volume of water present in the foaming composition. In other embodiments, the foaming agent is present in an amount in the range of about 0.5% and about 5% by volume of water present in the foaming composition.
    Nonionic surfactants In some embodiments, useful nonionic surfactants include, but are not limited to esters of fatty acids, glycerol esters, ethoxylated esters of glycol fatty acids, esters of ethoxylated polyethylene glycol fatty acids, amines, esters of sorbitan, alkoxylates of secondary alcohols, alkoxylates of alkylphenol. Typical non-ionic surfactants are glycerol esters, glycol ethoxylated fatty acid esters and polyethylene glycol ethoxylated fatty acid esters.
    Selected non-ionic surfactants have the structures: R3C (O) O- (CH2CH2O) p-R4; and R3C (O) OCH2CH (OH) CH2O-R4 and their combinations.
    R3 is a hydrocarbon chain that contains about 10 to about 22 carbon atoms and can be branched or linear and saturated or unsaturated; R4 hydrogen or a hydrocarbon chain containing about 1 to about 20 carbon atoms and can be branched or linear and saturated or unsaturated; "p" is about 1 to about 20, preferably about 5 to about 20, more preferably about 5 to about 12.
    The amines have the following structural formula:
    wherein R1 is a hydrophobic portion of alkyl, alkylarylalkyl, alkoxyalkyl, alkylaminoalkyl or alkylamidoalkyl, and where R1 has from about 10 to about 22 carbon atoms and can be branched or linear and saturated or unsaturated. R2 and R3 are, independently, i) an aliphatic group or ii) an aliphatic group with a radical with an aromatic or benzyl moiety attached thereto. R2 and R3, have from 1 to about 20 atoms. The aliphatic group can be branched or linear and saturated or unsaturated. R2 and R3 can be independently, for example, alkyl, oxyalkyl, polyoxyalkyl, alkoxy, and alkylaryl. Typically, R2 and R3 are alkyl groups. More typically, R2 and R3 are, independently, groups, methyl or ethyl.
    Representative amines of the above structure include polyoxyethylenated cocoalkylamines (2-15), polyoxyethylenated tallow alkylamines (12-18), and polyoxyethylenated oleyl and erucyl amines (2-15).
    Cationic surfactants In some embodiments, useful cationic surfactants include, but are not limited to: i) quaternary salts and ii) amine oxides, iii) and combinations thereof. Some representative cationic surfactants are shown below.
    Quaternary salts having the structural formula:
    wherein R1 is a hydrophobic moiety of alkyl, alkylarylalkyl, alkoxyalkyl, alkylaminoalkyl or alkylamidoalkyl, and where R1 has from about 10 to about 22 carbon atoms and can be branched or linear and saturated or unsaturated. R2 and R3 are, independently, i) an aliphatic group or ii) an aliphatic group with a radical with an aromatic or benzyl moiety attached thereto. R2, R3, and R5 have from 1 to about 20 atoms. The aliphatic group can be branched or linear and saturated or unsaturated. R2, R3, and R5 can be, for example, alkyl, oxyalkyl, polyoxyalkyl, alkoxy and alkylaryl. Preferably, R2, R3, and R5 are alkyl groups. More preferably, R2, R3, and R5 are methyl or ethyl groups. X is a suitable counterion, such as Cr-, Br-, and CH3CH3SO4-. Anionic surfactants In some embodiments, useful anionic surfactants include, but are not limited to, dodecylbenzenesulfonates, alpha olefin sulfonates, internal olefin sulfonates, diphenyloxide disulfonates, alkyl naphthalene sulfonates, alkyl sulfates, sulfates, sulfosuccinates, sulfosuccinates, sulfates , condensates of naphthalene-formaldehyde, alkyl sulfoesters and alkyl sulfoamides and their mixtures. Some non-limiting examples include alpha olefin sulfonates, sulfonates, alkyltholuene sulfonates, alkylxylene sulfonates, alpha olefin sulfonate dimers, hydroxyl sulfonates, alkenesulfonates, internal olefin sulfonates.
    Representative anionic surfactants include those of the following structural formulas:
    and their combinations. R1 is selected from the group consisting of alkyl, aryl, alkaryl, alkylarylalkyl, arylalkyl, alkylamidoalkyl and alkylaminoalkyl, where the alkyl group has about 10 to about 18 carbon atoms, where the aryl group represents a phenyl portion, diphenyl, diphenyl ether, or naphthalene. R2 is selected from a group consisting of hydrogen, -CH2CH2OH, alkyl, aryl, alkaryl, alkylarylalkyl, arylalkyl, alkylamidoalkyl and alkylaminoalkyl, where the alkyl group has about 10 to about 18 carbon atoms, where the aryl group represents a phenyl, diphenyl, diphenyl ether, or naphthalene moiety. "P" is from 0 to about 10, preferably from 0 to about 5.
    M is hydrogen, an alkali metal, such as sodium or potassium, or an ammonium salt. M is preferably an alkali metal, such as sodium or potassium, preferably sodium. In other embodiments, useful anionic surfactants include, but are not limited to, compounds according to the following structural formulas, as well as mixtures thereof: ROSO3- R (OCH2CH2) m (OCH2CHCH3) n) pOSO3- RSO3- R ((OCH2CH2) m '(OCH2CHCH3) n') p'OCH2CH (OH) CH2SO3- RC6H4SO3- where R represents an alkyl, arylalkyl group, or a hydroxyalkyl group, each m, n, m ', en' represents, independently, an integer from 0 to about 50 epep 'are each integers from 1 to about 25. R has about 10 to about 24 carbon atoms and more preferably about 12 to about 20 carbon atoms . R can be saturated or unsaturated, branched or straight-chain, where the branched alkyl groups have from 1 to about 6 carbon atoms. Representative alkyl groups for R include decyl, dodecyl, tetradecyl (myristyl), hexadecyl (cetyl), octadecyl (oleyl), stearyl, erucil, and derivatives of coconut, tallow, soy, and rapeseed oils.
    In one embodiment of the compound according to formula (II), men are each 0. In another embodiment of the compound according to formula (II), one of the men is 0 and the other is different from zero. In another embodiment of the compound according to formula (II), m and n are each non-zero. In one embodiment of the compound according to formula (IV), m 'and n are each 0. In another embodiment of the compound according to formula (IV), one of m' and n is 0 and the other is different from zero. In another embodiment of the compound according to formula (IV), m 'and n' are each non-zero.
    If both types of alkylenoxy units are present in the compounds according to structures (II) or (IV), that is, if the omen of the compound according to structure (II) are each non-zero, or, if m 'en' of the compound according to structure (IV) are each zero, then such alkyleneoxy groups can be alternately arranged in a random or block order.
    In one embodiment, the total number of alkyleneoxy groups per molecule, which is, in the case of the compound according to formula (II), the sum of the number of alkyleneoxy groups, (m + n), for the number of units , p, of such alkyleneoxy groups, and in the case of the compound according to formula (IV), the sum of the number of alkyleneoxy groups, (m '+ n'), for the number of units, p 'of such groups alkylenoxy, ranges from 0 to about 35 and more preferably from 0 to about 10. Zwitterionic surfactants In some embodiments, useful zwitterionic surfactants include, but are not limited to compounds that have the formula:
    where R1 represents a hydrophobic protection of alkyl, alkylarylalkyl, alkoxyalkyl, alkylaminoalkyl and alkylamidoalkyl, where alkyl represents a group containing about 10 to about 24 carbon atoms that can be branched or linear and can be saturated or unsaturated. Representative long-chain alkyl groups include tetradecyl (myristyl), hexadecyl (cetyl), octadecenyl (oleyl), octadecyl (stearic), docosenoic (erucol) and derivatives of tallow, coconut, soy and rapeseed oils. Typical alkyl groups have about 16 to about 22 carbon atoms. Representative of alkylamidoalkyl is alkylamidopropyl with alkyl being as described above. R2 and R3 are independently an aliphatic chain (that is, as opposed to aromatic at the atom attached to the quaternary nitrogen atom, for example, alkyl, arylalkyl, hydroxyalkyl, carboxyalkyl, and hydroxyalkyl-polyoxyalkylene, for example, hydroxyethyl-polyoxyethylene or hydroxypropyl-polyoxypropylene ), having from 1 to about 50 carbon atoms, in other embodiments from about 1 to about 20 carbon atoms, in other embodiments from about 1 to about 10 carbon atoms and in still others embodiments of about 1 to about 6 carbon atoms in which the aliphatic group can be branched or straight, saturated or unsaturated. Examples of alkyl chains are methyl, ethyl, preferred arylalkyl is benzyl, and preferred hydroxyalkyls are hydroxyethyl or hydroxypropyl, while preferred carboxyalkyls are acetate and propionate. Examples of hydroxyalkyl-polyoxyalkylenes are hydroxyethyl-polyoxyethylene and hydroxypropyl-polyoxyethylene. R4 is a hydrocarbyl radical (for example, alkylene) with a chain length of 1 to 4. In one embodiment, R4 is a methylene or ethylene group. Y is COO- or CH (OH) CH2SO3- or SO3-
    Specific examples of suitable zwitterionic surfactants include the following structures:
    wherein R1, R2, R3 have been defined hereinbefore.
    Another example of a suitable zwittenonic surfactant selected is an amine oxide. This material has the following structure:
    where Ri, R2, and R3 are as defined above. Other representative zwitterionic surfactants include tallow dehydroxyethyl glycinate, propionates, oleamidopropyl betaine, and erucyl amidopropyl betaine. Amphoteric surfactants Examples of amphoteric surfactants include, but are not limited to, those represented by the following formula:
    where R1, R2, and R4 are the same as defined above. Other specific examples of amphoteric surfactants include the following structures:
    where R1 has previously been defined herein, and X + is an inorganic cation, such as Na +, K +, NH4 + associated with a carboxylate group or a hydrogen atom in an acidic medium.
    Useful zwitterionic and amphoteric surfactants include those disclosed in U.S. Patent Nos. 6,831,108 B2 and 7,461,694 B2, which are hereby incorporated by reference.
    The treatment fluid optionally has one or more members of the group of organic acids, salts of organic acids and inorganic acids, and inorganic salts. Organic acid, or its salt, assists in the development of an increase in viscosity. Since brackish water is often used as a treatment fluid in the oil field, the salt content at some level may already be present.
    Useful organic acids are typically those of a sulfonic acid or a carboxylic acid. Anionic counterions of organic acid salts are typically sulfonates or carboxylates. Representatives of such organic molecules include aromatic sulfonates and carboxylates, such as p-toluenesulfonate, naphthalenesulfonate, chlorobenzoic acid, salicylic acid, phthalic acid and the like, where such counterions are soluble in water. Most preferred are salicylate, phthalate, p-toluene sulfonate, hydroxynaphthalene carboxylates, for example, 5-hydroxy-1-naphthoic acid, 6-hydroxy-1-naphthoic acid, 7-hydroxy-1-naphthoic acid, 1-hydroxy-2-naphthoic acid, preferably 3-hydroxy-2-naphthoic acid, 5-hydroxy-2-naphthoic acid, 7-hydroxy-2-naphthoic acid, and 1,3-hydroxy-2-naphthoic acid and 3 , 4-dichlorobenzoate. The organic acid or its salt will optionally be present in the treatment fluid from about 0.1% by weight to about 10% by weight, more typically from about 0.1% by weight to about 7% by weight, and even more typically from about 0.1% by weight to about 6% by weight, based on the total weight of the treatment fluid.
    Useful inorganic acids and salts include water-soluble potassium, sodium, and ammonium salts, such as potassium chloride and ammonium chloride. In addition, calcium chloride, calcium bromide and zinc halide salts can also be used. The inorganic salt is optionally present in the treatment fluid at a concentration of weight from about 0.1% by weight to about 30% by weight, more typically from about 0.1% by weight to about 10 % by weight, and even more typically from about 0.1% by weight to about 8% by weight. Organic salts, for example, trimethylammonium hydrochloride and tetramethylammonium chloride, can also be used in addition to, or as a substitute for inorganic salts.
    One of the components of the treatment fluid is water. In one embodiment, water will be a major amount, by weight, of the fluid. In other embodiments, however, water will not be the main component, by weight, of the fluid. The water can come from any source, as long as the source does not contain contaminants that are chemically or physically incompatible with the other components of the fluid (for example, causing undesirable precipitation). The water does not need to be potable and can be brackish and contain salts of metals such as sodium, potassium, calcium, zinc, magnesium, etc., or other materials typical of water sources in or near oil fields.
    Optionally, natural or synthetic polymers can be added to the treatment fluid to further regulate viscosity. Useful polymers include, but are not limited to, guar and guar gum, xanthan, polyacrylamide derivatives (PAM), starch and starch derivatives, cellulosic derivatives, and polyacrylates.
    The treatment fluid can contain a gas, such as air, nitrogen, natural gas and carbon dioxide to provide an energized fluid or foam. Supercritical carbon dioxide may also be present.
    Optionally, other surfactants, polymeric or non-polymeric, can be added to the treatment fluid to provide additional IFT reduction and / or modify viscosity. Such other surfactants can impact IFT and / or viscosity. Other useful surfactants can be anionic, cationic, non-ionic, zwitterionic amphoteric and their combinations. When present, the other surfactants will preferably be present in limited amounts, that is, about 0.5% or less, more preferably about 0.2% or less, and even more preferably 0.1% or less by weight. , based on the total weight of the treatment fluid.
    The treatment fluid provides the advantage of substantially reducing or preventing the infiltration of gas from gas support formations adjacent to the fracture network of the oil formation and reservoir. The reduction or prevention of gas infiltration allows the internal pressure and the formation and reservoir to be substantially maintained. Maintaining internal pressure prevents migration or pulls down oil within formations containing oil to be minimized or avoided making the oil easier to recover.
    EXAMPLES In the following example, the foam stability obtained, with the foam stabilizer described here, which in one embodiment is alkyl starch propyl sulfobetaines (also denoted as sultaines) is measured. The foam stability of the formulations described herein is compared to those of the formulations as described in WO2010 / 068082.
    The test is carried out at 25 ° C and at atmospheric pressure according to the following protocol: - 7 ml of aqueous surfactant formulation are placed in the bottom of a 30 ml tube of Allihn filter volume. This system consists of about 30 mL of straight tube (2 cm in diameter, 10 cm high) with a frit with a characteristic pore size that varies between 10 and 16 mm, mounted on the bottom of the tube (VWR International). - Nitrogen gas is injected at 50 mL / min flow rate for 30 seconds into the bottom of the filter tube through the frit in the aqueous formulation. The foam can form, which initially fills the tube completely. - Foam height is recorded as a function of time using a CCD camera. A first, rapid drop in height of the foam is observed in the first ten minutes of the experiment and is linked to gravity drainage through the foam lamellae. According to the experimental protocol described in [Georgieva et al., Soft Matter, 5, 2063, 2009], the initial foam height ho is chosen as the foam height after this first gravity drainage phase (10 minutes after the beginning of the experiment).
    Foam height h is then measured every minute after the gravity drain phase and compared to the initial foam height ho. The surfactants used are listed below: Cocamido propyl betaine: Mirataine BET C30 manufactured by Rhodia. C12 alpha olefin sulfonate: Calsoft AOS 1245 manufactured by Pilot. Hydroxypropyl sultaine cocamido: Mirataine CBS manufactured by Rhodia. C22 starch propyl hydroxy sultaine Lauryl trimethyl ammonium chloride: Arquad 1237 manufactured by Akzo. All formulations are tested at 0.66% by weight of total surfactant, in deionized water and include (expressed for a 100% surfactant formulation): - Formulation 1: 50% by weight of cocamido propyl betaine, 50% by weight of C12 alpha olefin sulfonate. - Formulation 2: 50% by weight of cocamido propyl hydroxy sultaine, 50% by weight of C12 alpha olefin sulfonate. - Formulation 3: 50% by weight of C22 propyl hydroxy sultaine starch, 50% by weight of C12 alpha olefin sulfonate. - Formulation 4: 50.3% by weight of cocamido propyl betaine, 45.7% by weight of C12 alpha olefin sulfonate, 4% of lauryl trimethyl ammonium chloride. - Formulation 5: 50.3% by weight of cocamido propyl hydroxy sultaine, 45.7% by weight of C12 alpha-olefin sulfonate, 4% of lauryl trimethyl ammonium chloride. - Formulation 6: 50.3% by weight of C22 propyl hydroxy sultaine starch, 45.7% by weight of C12 alpha-olefin sulfonate, 4% of lauryl trimethyl ammonium chloride.
    Formulations 1 and 4 serve as a reference to illustrate a foaming composition using the foam stabilizer described herein. The results, expressed as a percentage of the initial foam height as a function of time (h (t) / ho) after 1, 2, 3 and 4 hours were reported in table 1.
    The results show an increase in foam stability when the cationic ammonium lauryl chloride compound is added to a mixture of amphoteric propyl cocamido and a C12 alpha olefin sulfonate. The results also show that, within the experimental error, 5 propyl cocamido hydroxy sultaines provide foam stability comparable to that obtained with cocamido propyl betaine. The same trend is observed with C22 starch propyl hydroxy sultaines that provide comparable foam stability, and even slightly higher than C12 10 cocamido propyl betaines. Therefore, while providing technical advantages such as less adsorption (possibly) on reservoir rock and an improved thermal stability compared to betaine, sultaines prove to be as efficient as in foam stabilization when used in formulations as described in WO 2010 / 068082. Table 1: foam height as a function of time for the selected formulations


    It should be understood that the foregoing description is only illustrative of the present disclosure. Various alternatives and modifications can be devised by those skilled in the art without departing from disclosure. Therefore, the present description is intended to cover all such alternatives, modifications and variations that fall within the scope of the appended claims.
    权利要求:
    Claims (22)
    [0001]
    1. A method for increasing oil recovery from an oil formation inside a reservoir, CHARACTERIZED by the fact that it comprises: (a) introduction of a foaming composition comprising an alpha olefin sulfonate under pressure in the oil formation; (b) introduction of a gas under pressure in the oil formation, in which the presence of the foaming composition affects the gas flow within the oil formation; and (c) extraction of oil through a well in the reservoir, where the foaming composition comprises a foam stabilizer chosen from alkyl amidopropyl hydroxy sulfobetaine, or alkyl hydroxy sulfobetaine, where the alkyl group is an integer number of 10 atoms carbon to 24 carbon atoms.
    [0002]
    2. Method, according to claim 1, CHARACTERIZED by the fact that the alkyl group is an integer number from 12 carbon atoms to 24 carbon atoms.
    [0003]
    3. Method according to claim 1, CHARACTERIZED by the fact that the alkyl group is an integer from 18 carbon atoms to 24 carbon atoms.
    [0004]
    4. Method, according to claim 1, CHARACTERIZED by the fact that the foaming composition also comprises water and, optionally, a foaming gas.
    [0005]
    5. Method, according to claim 1, CHARACTERIZED by the fact that the gas comprises carbon dioxide, air, nitrogen, natural gas, steam, flue gas or any combination thereof.
    [0006]
    6. Method, according to claim 1, CHARACTERIZED by the fact that the step of introducing the foaming composition into an oil formation includes the introduction of the foaming composition into one or more fracture nets located within the oil formation.
    [0007]
    7. Method, according to claim 1, CHARACTERIZED by the fact that the step of introducing the gas in an oil formation includes the introduction of the gas in one or more portions of the matrix located within the oil formation.
    [0008]
    8. Method, according to claim 1, CHARACTERIZED by the fact that the foaming composition still comprises a cationic polymer.
    [0009]
    9. Method, according to claim 1, CHARACTERIZED by the fact that the foaming composition still comprises a cationic polymer selected from the group consisting of galactomannan gums and their derivatives, glucomannan gums and their derivatives, guar gum, locust bean gum, face, hydroxyethyl guar, hydroxypropyl guar, cationically modified cellulose, hydroxypropyl cellulose, hydroxymethyl cellulose, hydroxyethyl cellulose, acrylamide, polyvinyl alcohol, an acrylamide copolymer, and combinations thereof, having a quaternized amine functionality.
    [0010]
    10. Method according to claim 1, CHARACTERIZED by the fact that the foaming composition still comprises a synthetic polymer comprising copolymers of 1-vinyl-2-pyrrolidine and its salts, copolymers of 1-vinyl-3-methyl salts imidazolium, copolymers of 1-vinyl-2-pyrrolidine, copolymers of dimethylaminoethyl methacrylate, polymers of dimethyldiallammonium chloride, acrylamide copolymers, copolymers of dimethyldylammonium chloride, cationic polyacrylamides.
    [0011]
    11. Method for increasing the oil recovery of an oil formation from inside a reservoir, CHARACTERIZED by the fact that it comprises: (a) introduction of a foaming composition comprising an alpha olefin sulfonate under pressure in the oil formation; (b) introduction of a gas under pressure in the oil formation, in which the presence of the foaming composition affects the gas flow within the oil formation; and (c) extraction of oil through a well in the reservoir, in which the foaming composition comprises a foam stabilizer that has the formula (I):
    [0012]
    12. Method according to claim 11, CHARACTERIZED by the fact that the alkyl group is an integer number from 12 carbon atoms to 24 carbon atoms.
    [0013]
    13. Method according to claim 11, CHARACTERIZED by the fact that the alkyl group is an integer from 18 carbon atoms to 24 carbon atoms.
    [0014]
    14. Method according to claim 11, CHARACTERIZED by the fact that R1 is the alkyl starch group, the alkyl starch group having formula (II):
    [0015]
    15. Method according to claim 14, CHARACTERIZED by the fact that R7 represents a linear or branched alkyl group having more than 16 carbon atoms.
    [0016]
    16. Method, according to claim 11, CHARACTERIZED by the fact that the foam stabilizer is of formula (III)
    [0017]
    17. Method, according to claim 11, CHARACTERIZED by the fact that the foaming composition has up to 9 Kg / l (20 lbs / gallon) of water from organic and inorganic salts.
    [0018]
    18. Method according to claim 11, CHARACTERIZED by the fact that the step of introducing the foaming composition into an oil formation includes introducing the foaming composition into one or more fracture nets located within the oil formation.
    [0019]
    19. Method according to claim 11, CHARACTERIZED by the fact that the step of introducing the gas into an oil formation includes introducing the gas into one or more portions of the matrix located within the oil formation.
    [0020]
    20. Method, according to claim 11, CHARACTERIZED by the fact that the foaming composition still comprises a cationic polymer.
    [0021]
    21. Method, according to claim 11, CHARACTERIZED by the fact that the foaming composition still comprises a cationic polymer selected from the group consisting of galactomannan gums and their derivatives, glucomannan gums and their derivatives, guar gum, locust bean gum, face, hydroxyethyl guar, hydroxypropyl guar, cationically modified cellulose, hydroxypropyl cellulose, hydroxymethyl cellulose, hydroxyethyl cellulose, acrylamide, polyvinyl alcohol, an acrylamide copolymer, and combinations thereof, having a quaternized amine functionality.
    [0022]
    22. Method according to claim 11, CHARACTERIZED by the fact that the foaming composition further comprises a synthetic polymer comprising copolymers of 1-vinyl-2-pyrrolidine and its salts, copolymers of 1-vinyl-3-methyl- salts imidazolium, copolymers of 1-vinyl-2-pyrrolidine, copolymers of dimethylaminoethyl methacrylate, polymers of dimethyldiallammonium chloride, acrylamide copolymers, copolymers of dimethyldylammonium chloride, cationic polyacrylamides. 5
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    同族专利:
    公开号 | 公开日
    BR112013029345A2|2017-02-07|
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    CA2836064C|2020-07-14|
    EP2707571A2|2014-03-19|
    WO2012158489A3|2013-03-14|
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    CN103649459A|2014-03-19|
    MY151309A|2014-05-07|
    MX2013003029A|2013-06-17|
    RU2013150923A|2015-06-20|
    US8985206B2|2015-03-24|
    US20120285694A1|2012-11-15|
    EP2707571B1|2020-10-07|
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    2018-12-11| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2019-11-12| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-04-28| B25A| Requested transfer of rights approved|Owner name: IFP ENERGIES NOUVELLES (FR) |
    2020-06-09| B25L| Entry of change of name and/or headquarter and transfer of application, patent and certificate of addition of invention: publication cancelled|Owner name: RHODIA OPERATIONS (FR) Free format text: ANULADA A PUBLICACAO CODIGO 25.1 NA RPI NO 2573 DE 28/04/2020 POR TER SIDO INDEVIDA. |
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    2021-01-19| B09A| Decision: intention to grant|
    2021-02-23| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 11/05/2012, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US201161518904P| true| 2011-05-13|2011-05-13|
    US61/518,904|2011-05-13|
    PCT/US2012/037442|WO2012158489A2|2011-05-13|2012-05-11|Enhanced foam stability applications and methods|
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