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    • 专利摘要:
    surfactant composition and aqueous concentrate useful for oil recovery, injectable product made to dilute the concentrate and surfactant composition, petroleum microemulsion in low viscosity water, stable and method. surfactant compositions useful for oil recovery are disclosed. The compositions comprise from 1 to 80% by weight of a propoxylated c12-c20 alcohol sulfate, from 1 to 80% by weight of a c12-c20 internal olefin sulfonate, and from 0 to 1% by weight of a sulfate of c4-c12 ethoxylated alcohol. including a lower proportion of ethoxylated alcohol sulphate reduces or eliminates the need to rely on costly cosolvents to dye good performance in enhanced oil recovery processes. in particular, low interfacial stresses and low microemulsion viscosities can be achieved when ethoxylated alcohol sulphate accompanies propoxylated alcohol sulphate and internal olefin sulphonate. aqueous concentrates comprising water and the surfactant compositions described above are also disclosed. diluting the surfactant composition the surfactant or aqueous concentrate composition with water or brine to the desired levels of anionic assets provides an injectable composition useful for eor applications. petroleum microemulsions in low-viscosity, stable water comprising crude oil, water, and surfactant compositions are also disclosed.
    公开号:BR112013029462B1
    申请号:R112013029462-0
    申请日:2012-05-14
    公开日:2021-02-23
    发明作者:Ramakrishna Ravikiran；Jieyuan Zhang
    申请人:Stepan Company；
    IPC主号:
    专利说明:

    FIELD OF THE INVENTION
    The invention relates to surfactants useful for the recovery of petroleum and aqueous concentrates comprising surfactants. BACKGROUND OF THE INVENTION
    The development of crude oil and oil production with formations can include up to three phases: preliminary, secondary and tertiary (or reinforced) recovery. During preliminary recovery, the natural energy present in the formation (for example, water, gas) and / or gravity directs the oil into the production well orifice. As oil is produced from a formation carrying oil, pressures and / or temperatures within the formation may decline. Artificial lifting techniques (such as pumps) can be used to bring the oil to the surface. Only about 10 percent of an original oil from the on-site reservoir (OOIP) is typically produced during preliminary recovery. Secondary recovery techniques are employed to extend the productive life of the field and generally include injecting a displacement fluid such as water (water flood) to displace the oil and lead it to a production well orifice.
    Secondary recovery techniques typically result in the recovery of an additional 20 to 40 percent OOIP from the reservoir. However, even if water floods were to continue indefinitely, typically more than half of the OOIP would remain unrecovered. Efficiency of poor mixing between water and oil (because of the high interfacial tension between water and oil), capillary forces in the formation, the temperature of the formation, the salinity of the water in the formation, the composition of the oil in the formation, sweep poor water injected through training, and other factors contribute to inefficiency. Preliminary and secondary techniques therefore leave a significant amount of oil in the reservoir.
    With much of the easy-to-produce oil already recovered from oil fields, producers have employed tertiary or enhanced oil recovery (EOR), techniques that offer the potential to recover 30 to 60 percent or more of OOIP from a reservoir. Three main categories of EOR have succeeded commercially: thermal recovery, gas injection and chemical techniques. Thermal recovery introduces heat (for example, steam injection) to lower the viscosity of crude oil to improve its ability to flow through the reservoir. Gas injection uses nitrogen, carbon dioxide, or other gases that expand in a reservoir to push additional oil into a production well orifice. Other gases dissolve in the oil to lower its viscosity and improve its fluidity. Chemical techniques inject surfactants (surfactant flooding) to reduce the interfacial tension that prevents or inhibits oil droplets from moving through a reservoir or inject polymers that allow the oil in the formation to move more easily through the formation.
    Chemical techniques can be used before, during, or after performing preliminary and / or secondary recovery techniques. Chemical techniques can also complement other EOR techniques. Surfactant flooding includes flooding with surfactant polymer (SP) and flooding with alkaline surfactant polymer (ASP). In the SP flood, a reservoir is injected with water and / or brine containing ~ 1% by weight of surfactant and ~ 1% by weight of polymer. ASP flooding includes alkali in addition to the components used in the SP flooding. ASP systems typically contain ~ 0.5 to 1% by weight of alkali to ~ 0.1 to 1% by weight of surfactant, and ~ 0.1 to 1% by weight of polymer. Typically, an SP or ASP flood is followed by an injection of a displacement fluid, for example, a flood of water and / or "push" polymer fluid. The choice between SP or ASP depends on the acid value of the oil to be recovered, the concentration of divalent cations in the reservoir brine, the project economy, the ability to perform water softening or desalination, and other factors. Alkali hijacks divalent cations in the formation brine and thus reduces the adsorption of the surfactant during displacement through the formation. Alkali also generates an anionic surfactant (sodium naphthenate soap) at the site in the formation by reacting with naphthenic acids that are naturally present in crude oil. The use of relatively cheap alkali reduces the retention of the surfactant and consequently reduces the amount of surfactant required, and therefore also reduces the total cost. Alkali can also help change the wettability of the formation to a wetter state of water to improve the rate of imbibition.
    In the “change in wettability”, another EOR technique, surfactants are introduced into a reservoir, sometimes combined with changes in the electrolyte concentration, to displace the adsorbed oil by spontaneously imbibing the water on the reservoir rock. This technique does not necessarily require low interfacial stresses between the oil and the aqueous phases or the formation of a microemulsion phase. It also does not require good displacement fluid sweeping efficiency, and as such it could be useful in carbonate reservoirs that can be fractured and typically have poor conformation. Surfactants used in floods by SP and ASP were also useful in altering wettability.
    A surfactant system, after injection into a formation carrying oil, takes crude oil and brine from the formation to form a multi-phase microemulsion at the site. When complete, the microemulsion is immiscible with the crude reservoir and exhibits low interfacial tension (IFT) with crude oil and brine. Commercial surfactant EOR processes reach ultra-low IFTs (ie less than 10'2 mN / m) to mobilize disconnected drops of crude oil in the formation and create an oil bank where both oil and water flow as continuous phases. IFT changes with salinity, surfactant composition, crude oil composition, formation temperature, and other variables. For anionic surfactants, an optimal salinity exists in which the microemulsion solubilizes equal volumes of oil and water, and in which the microemulsion exhibits almost equal IFTs with oil and brine, the ultra low IFT generally exists only in a narrow overlapping salinity range. the optimal salinity for a given microemulsion.
    As explained by P. Zhao et al. (“Development of High-Performance Surfactants for Difficult Oils,” SPE / DOE Improved Oil Recovery Symposium, Tulsa, OK, April 2008, SPE 113432), “selecting surfactants for enhanced oil recovery applications requires laboratory testing with oil crude from the target reservoir and can involve considerable effort to find a suitable surfactant and other components such as polymer, electrolytes, co-surfactant and co-solvent ”.
    Anionic surfactants used in EOR applications included alkyl aryl sulfonates (AAS), a-olefin sulfonates (AOS), internal olefin sulfonates (IOS), ether alcohol sulfates derived from propoxylated C12-C2o alcohols, and mixtures thereof. Sulfonates are normally made by reacting an alkylate, a-olefin, or internal olefin with sulfur trioxide in the presence of an inert gas, followed by neutralization. Internal olefin sulphonates have only one polar head and two support tails. Recently, it has been reported that IOS derived from internal olefins having a high production of 1,2-dissubstitution conveys performance advantages for EOR applications (see Publ. De Ped. De Pat. No. US 2010/0282467). In particular, the optimal salinities of microemulsions made from sulfonates derived from internal olefins containing low amounts of tri-substituted olefins have been found to be significantly lower than the optimal salinities of microemulsions made from sulfonates derived from internal olefins of the same length of carbon that contain appreciable amounts of olefins. tri-substituted. Internal olefins with high 1,2-dissubstitution are conveniently available from the metathesis of raw materials containing a-olefin, while other internal olefins can be produced by agglomeration of olefin, Fischer-Tropsch processes, catalytic dehydrogenation, thermal cracking and other known processes.
    EOR compositions were made by combining IOS with a nonionic surfactant such as an ethoxylated alcohol or mixtures of an alcohol and an ethoxylated alcohol (see Publ. De Ped. De Pat. No. US2009 / 0203557). According to publication 557, a relatively high proportion of the nonionic surfactant (up to 25% based on the amount of IOS used) may be necessary to justify its injection into a reservoir. The reference does not suggest combining internal olefin sulfonates with sulfated ethoxylated alcohols or other anionic surfactants.
    Among many possible combinations of surfactants, a mixture of an IOS derived from a C15-Ci8 olefin and a sulfate ether derived from a C16-Ci7 propoxylated alcohol have shown promise in West Texas dolomite core flooding experiments (see D. Levitt et al ., “Identification and Evaluation of High Performance EOR Surfactants,” SPE / DOE Symposium on Enhanced Oil Recovery, Tulsa, OK, April 2006, SPE 100089). The authors investigated propoxylated materials having 3, 5 or 7 PO units per molecule, particularly 7 PO units (see Tables 1 and 2 on page 7 of the Levitt paper). Typically, about a 3: 1 ratio by weight of C16-C17 alcohol sulfate propoxylated to IOS C15-C18 was used. The authors favored a formulation containing this mixture of surfactant and 2% by weight of sec-butyl alcohol as a cosolvent because it exhibited a solubilization ratio under optimal conditions. When sec-butyl alcohol was omitted or reduced to 0.5% L • by weight, however, the microemulsion was viscous and an optimal solubilization ratio could not be determined (see Table 2). Use of a cosolvent is a common tactic to avoid microemulsions of high viscosity or gel phase, expanding the range over which desirably low IFTs are obtained, and / or improving the aqueous stability of chemical components. Although this makes the formulation more robust for field implementation, cosolvents can make the formulation expensive, so its use is preferably avoided or at least minimized.
    The EOR industry benefits from the identification of new surfactants or 10 combinations of surfactants with performance advantages. In particular, surfactants that can promote low interfacial tension between aqueous and hydrocarbon phases in geological formations are highly desirable. They are also valuable surfactants that can generate stable, low viscosity microemulsions with viscous oils particularly in the absence of turbulent flow conditions. Ideally, good performance could be achieved with reduced confidence in cosolvents, which add considerably to the cost of the formulation. SUMMARY OF THE INVENTION
    In one aspect, the invention relates to surfactant compositions useful for oil recovery. The compositions comprise from 10 to 80% by weight of a propoxylated C12-C20 alcohol sulfate, from 10 to 80% by weight of an internal olefin C12-C2o sulfonate, and from 0.1 to 10% by weight of propoxylated sulfate. ethoxylated C4-C12 alcohol.
    It has been found that by including a lower proportion of ethoxylated alcohol sulfate 25, the need to rely on costly cosolvents to achieve good performance in enhanced oil recovery processes is reduced or eliminated. In particular, it has been found that interfacial stresses and lower microemulsion viscosities can be achieved when ethoxylated alcohol sulphate accompanies propoxylated alcohol sulphate and internal olefin sulphonate.
    In another aspect, the invention relates to aqueous concentrates comprising water and surfactant compositions. Dilution of the surfactant or aqueous concentrate composition with water or brine to the desirable level of anionic assets, typically 0.01 to 5% by weight, provides an injectable composition useful for EOR applications. In addition, the invention includes stable, low viscosity oil-in-water microemulsions comprising crude oil, water and surfactant compositions. BRIEF DESCRIPTION OF THE FIGURES
    Fig. 1 illustrates phase behavior test for a comparative surfactant formulation that uses a propoxylated alcohol sulfate, an internal olefin sulfonate, and a cosolvent. Fig. 2. is a graph of the solubilization ratio versus sodium chloride concentration for the comparative surfactant formulation. 10 Fig. 3 is a set of four viscosity versus shear curves for microemulsions made using the comparative surfactant formulation and shows the impact of temperature and salinity on viscosity. Fig. 4 illustrates phase behavior test results for an inventive surfactant formulation that uses a propoxylated alcohol sulfate, an internal olefin sulfonate, and an ethoxylated C5-Cn alcohol sulfate, and includes a solubilization ratio graph. versus total dissolved solids (TDS) for the inventive surfactant formulation. Fig. 5 is a set of viscosity curves measured at four different salinities at 59 ° F (15 ° C) for microemulsions made using an inventive surfactant formulation. Fig. 6 is a set of viscosity curves measured at four different salinities at 82 ° F (28 ° C) for microemulsions made using an inventive surfactant formulation. Fig. 7 illustrates a typical phase study and behavior. 25 Fig. 8 shows how to calculate a solubilization ratio for a sample pipette. Fig. 9 shows how to determine an IFT at optimal salinity. DETAILED DESCRIPTION OF THE INVENTION
    In one aspect, the invention relates to surfactant compositions useful for oil recovery. The surfactant compositions comprise a propoxylated C12-C20 alcohol sulfate, a C12-C2o internal olefin sulfonate, and an ethoxylated C4-C12 alcohol sulfate.
    Suitable propoxylated C12-C2o alcohol sulphates are commercially available. For example, Petrostep ™ S1, a product made by reacting a 35 C16 alcohol with 7 molar equivalents of propylene oxide (PO) and sulfating the resulting propoxylated alcohol, and Petrostep ™ S13C, a product made by reacting a C13 alcohol with 7 molar equivalents of PO followed by sulfation, are available from Companhia Stepan.
    Propoxylated C12-C20 alcohol sulphates can also be synthesized. In a suitable approach, a propoxylated C12-C20 alcohol is sulfated and neutralized according to well-known methods. Propoxylated alcohol is normally reacted with sulfur trioxide in the presence of an inert gas and sometimes a solvent, which are used to help control the reaction temperature. After the complete reaction, sodium hydroxide and another base are added to convert groups of sulfonic acids to sulfate salts. Sulfate can be diluted with water to provide a desired level of assets. For example of suitable procedures for sulfation of propoxylated C12-C20 alcohols, see Pat. Nos. 3,544,613, 4,608,197, and 5,847,183, the teachings of which are incorporated herein by reference.
    Propoxylated alcohols can be made by reacting the corresponding C12-C20 alcohol with propylene oxide in the presence of base catalyst such as KOH according to well-known methods. Other catalysts, such as double metal cyanide complexes, can also be used for this purpose (see, for example, U.S. Pat. No. 5,482,908).
    The propoxylated C12-C20 alcohol sulphates preferably derive from Ci2-C18 alcohols, more preferably from C12-C14 or C16-Ci8 alcohols, and they preferably comprise, on average, from 2 to 10, more preferably from 3 to 8, and more preferably from 6 to 8 oxypropylene units.
    The amount of propoxylated alcohol sulfate in the surfactant composition is within the range of 10 to 80% by weight, preferably 10 to 40% by weight, more preferably 20 to 30% by weight.
    A second component of the surfactant composition is an internal olefin sulfonate C12-C20 (IOS). Suitable internal olefin sulphonates are also commercially available. For example, Petrostep ™ S2, a Ci5-Ci8 IOS, is available from Stepan Company. Additional suitable IO materials are available from Shell Chemical (Enordet ™ internal olefin sulfonates) and other suppliers.
    Suitable internal olefin sulfates can also be prepared by sulfonating an internal C12-C20 olefin or mixing internal olefins according to well known methods. In an appropriate approach, sulfonation is performed in a continuous thin film reactor maintained at 10 ° C to 50 ° C. The internal olefin or mixture is placed in the reactor together with sulfur trioxide diluted with air. The molar ratio of internal olefin to sulfur trioxide is maintained in a suitable ratio, for example, from about 0.7: 1 to about 1.1: 1. The sulfonated derivative of the internal olefin or mixture can be neutralized with alkali, for example, sodium hydroxide, to form the corresponding salt. The reaction is exothermic and the viscosity of the reaction product may depend on the amount of water present. General conditions and processes for sulfonation of olefins are disclosed in U.S. Pat. No. 4,252,192, the teachings of which are incorporated herein by reference.
    The internal olefin used as a source for IOS C12-C2o can be di, tri, or tetra-substituted with straight or branched alkyl groups. Internal olefin sources can be obtained from a variety of processes, including olefin oligomerization (eg, ethylene, propylene, butylene), a-olefin metathesis, Fischer-Tropsch processes, catalytic dehydrogenation of long-chain paraffins, thermal cracking of hydrocarbon waxes, and dimerized olefin vinyl processes. Well-known ethylene oligomerization process is the Shell higher olefin process (SHOP), which combines oligomerization of ethylene to form a-olefins, isomerization of a-olefins to form internal olefins, and metathesis of these internal olefins with butenes or ethylenes to form α-olefins of different chain lengths. Commercially available internal Olefins made by SHOP typically contain six per mol center or more of tri-substituted internal olefins. Internal olefin sulphonates and their preparation are described in many references, including Pat. US. US 4,532,053, 4,555,351, 4,597,879, and 4,765,408, and Publ. From Ped. Pat. No. US 2010/0282467, the teachings of which are incorporated herein by reference.
    In one aspect, the internal olefin used to make the IOS is produced by metathesis of an a-olefin has a high proportion of dissubstitution and a correspondingly low proportion of trisubstitution. Such internal olefin sulfonates, which are disclosed in Publ. From Ped. Pat. No. US 2010/0282467, provides advantages for EOR, including lower optimal salinities. The internal olefin sulfonate is derived from a C12-C20, preferably from internal C15-C18 olefin.
    The amount of C12-C2o internal olefin sulfonate in the surfactant composition is within the range of 10 to 80% by weight, more preferably 50 to 80% by weight, and most preferably from 60 to 75% by weight.
    A third component of the surfactant composition is an ethoxylated C4-C12 alcohol sulfate. Suitable ethoxylated C4-C12 alcohol sulfates can be obtained from Stepan Company and Shell Chemicals. An example is Petrostep ™ CS-207 from Stepan, it is made by ethoxylation of a C6-Cio alcohol with an average of 5 3 molar equivalents of ethylene oxide (EO), followed by sulfation with sulfur trioxide and neutralization to give a sulfate of sodium. Another suitable commercial material is Petrostep ™ CA-207 from Stepan, which is made by ethoxylating a C6-C10 alcohol with an average of 3 molar equivalents of EO, followed by sulfation with sulfamic acid and neutralization to give an ammonium sulfate. 10 Suitable ethoxylated alcohols also include products made by sulfating Neto and N1 Neodol ™ series ethoxylates, for example, Neodol N91-2.5, N91-5, N91-6, N-91-8, N91-8.4, and N1 ethoxylates -9. These products are derived from C9-C11 alcohols and have an average of 2.5, 5, 6, 8, 8.4 and 9 oxyethylene units, respectively. 15 C4-C12 ethoxylated alcohol sulphates can also be synthesized from the corresponding "plasticizer" or "oxo" alcohols by reacting the corresponding C4-C12 alcohol with EO in the presence of a base catalyst, sulfating the resulting ethoxylated alcohol with trioxide trioxide sulfur, chlorine sulfonic acid, sulfamic acid, or others, and neutralizing with sodium hydroxide, lithium hydroxide, potassium hydroxide, ammonia, ammonium hydroxide, or others. Consequently, the sulfate can have any desired cation, for example, sodium, lithium, potassium, ammonium, alkylammonium and the like. Preferably, the ethoxylated alcohol sulfate is derived from a C5-Cn alcohol, more preferably from a C6-C10 alcohol. The ethoxylated alcohol sulfate preferably has an average of 1 25 to 12, more preferably 2 to 6, even more preferably 2 to 4, and most preferably about 3 oxyethylene units.
    It was found that a relatively small proportion of ethoxylated C4-C12 alcohol sulfate can significantly improve the effectiveness of the surfactant formulation in an EOR application. In particular, lower IFTs 30 (for example, below 10'2 mN / m) and lower microemulsion viscosities can be achieved with a suitable crude oil source when the surfactant comprises 0.1 to 10% by weight, more preferably of 1 to 5% by weight, and more preferably 2 to 4% by weight, of the ethoxylated alcohol sulphate in combination with the propoxylated alcohol sulphate and internal olefin sulphonate. Our results below demonstrate that the advantages can be verified while coincidentally reducing or eliminating the need for a cosolvent (see Comparative Example 1 and Example 2, below), thus providing a substantial cost benefit.
    In a "tight" reservoir, the inventive surfactant composition must be suitable for use without additives, particularly where the surfactant composition acts as a rock wettability-altering agent or as an injectability enhancing agent. Normal concentrations range from 0.01 to 3% by weight in these applications. Here, the surfactant can also be used in conjunction with an alkaline compound (see list below).
    In another aspect, the invention is an aqueous concentrate useful for oil recovery. The aqueous concentrate comprises water and a surfactant composition comprising 10 to 80% by weight of a propoxylated C12-C20 alcohol sulfate, 10 to 80% by weight of a C12-C20 internal olefin sulfonate, and 0.1 10% by weight of an ethoxylated C4-C12 alcohol sulphate. Preferably, the aqueous concentrate comprises from 15 to 85% by weight of water, from 15 to 85% by weight of the surfactant composition, and from 0 to 50% by weight of one or more additives selected from the group consisting of co-surfactants, cosolvents, polymers, alkaline compounds, oxygen scavengers, and mixtures thereof. These optional additives are more fully described below.
    Co-surfactants Aqueous concentrates of the invention optionally include a co-surfactant. Suitable co-surfactants include anionic, non-ionic, zwitterionic, amphoteric and cationic surfactants. Anionic surfactants include, for example, internal olefin sulfonates, alkoxylated alcohol sulfates, alkoxylated alcohol sulfonates, alkyl-aryl sulfonates, a-olefin sulfonates, alkane sulfonates, alkane sulfates, alkylphenol sulfates, alkylamide sulfates, alkylamine sulfates, alkylamide ether sulfates, polyether alkylaryl sulfonates, alkylphenol sulfonates, lignin sulfonates, petroleum sulfonates, phosphate esters, alkali metal, ammonium salts or fatty acid amine (ie. "soaps"), fatty alcohol ether sulphates, alkyl ether carboxylates, N-acyl-N-alkyltaurates, arylalkane sulphonates, sulphosuccinate esters, alkyldiphenyl ethersulfonates, alkylnaphthalenesulphonates, naphthalenesulphonic acid-formaldehyde condensates, polyethylsulfate acid derivatives. fatty, sulfonated glyceride oils, fatty acid menoethanolamide sulfates, a-sulfonated fatty acid esters, N-acyl glutamat the, glycinated N-acyl, N-acyl alanates, acylated amino acids, and fluorinated anions. Suitable non-ionic surfactants include alkoxylated alkylphenols, alkoxylated alcohols, alkoxylated glycols, alkoxylated mescaptan, long-chain carboxylic acid esters, alkanolamine condensates, alkanolamides, tertiary acetylenic glycols, alkoxylated silicones, hydrocarbonyl ethoxyl ethoxylsulfoxides, copolysulfoxides , grease amine oxide, partial fatty acid glycol esters, fatty acid alkanolamides and alkyl polyglucosides. Suitable zwitterionic and amphoteric surfactants include, for example, C8-Ci8 betaines, C8-Ci8 sulfobetaines, C8-C24 alkylamido C1-C4 alkylenebetaines, 3-N-alkylaminopropionic acids, N-alkyl-3- 10 iminodipropionic acids, imidazoline carboxylates, N-alkylbetaines, amidoamines, amidobetaines, amine oxides, and sulfobetaines. Suitable cationic surfactants include, for example, long chain amines and corresponding salts, acylated polyamines, quaternary ammonium salts, imidazolium salts, alkoxylated long chain amines, quaternized long chain amines, and amine oxides.
    Cosolvents Aqueous concentrates of the invention optionally include a cosolvent. Suitable cosolvents include, for example, alcohols, ethers, esters, and the like. Lower alcohols, especially C2-C5 alcohols, are particularly preferred. Specific examples of suitable cosolvents include ethyl alcohol, n-propyl alcohol, isopropyl alcohol, isobutyl alcohol, n-butyl alcohol, sec-butyl alcohol, n-pentyl alcohol, sec-amyl alcohol, n-hexyl alcohol, n-octyl alcohol, 2-ethylhexyl alcohol, ethylene glycol n-butyl ether, diethylene glycol n-butyl ether, triethylene glycol n-butyl ether, propylene glycol methyl ether, propylene glycol methyl ether 25 acetate, lauryl alcohol ethoxylates, glycerin, poly (glycerine), polyalkylene alcohol ethers, polyalkylene glycols, poly (oxyalkylene) glycols, poly (oxyalkylene) glycol ethers, and the like, and mixtures thereof. Recovered cosolvents can be used. The cosolvent is normally used in an amount of 0.01% by weight to 3% by weight.
    Polymers The aqueous concentrate optionally includes a polymer, which is typically used to assist mobilization of oil through formation. Suitable polymers include, for example, polyacrylamides, partially hydrolyzed polyacrylamides having Mw values of 1 to 30 million (for example, 35 Flopaam ™ 3330S and Flopaam 3838S, SNF products, or Kypaam ™ 5, Beijing Hengju product), copolymers of acrylamide with aminopropylsulfonic acid or
    N-vinyl-2-pyrrolidone, polyacrylates, ethylene copolymers, biopolymers, carboxymethylcellulose, polyvinyl alcohols, polystyrene sulfonates, polyvinylpyrrolidones, 2-acrylamide-2-methylpropane sulfonates, or combinations thereof. Suitable ethylene copolymers include, for example, 5 copolymers of acrylic acid and acrylamide, acrylic acid and lauryl acrylate, and lauryl acrylate and acrylamide. Suitable biopolymers include, for example, xanthan gum, guar gum, scleroglucan, diutane, and the like. Weighted average molecular weights (Mw) of the polymers preferably range from 10,000 to 30 million. Polymers are normally used in concentrations from 50 to 5000 10 ppm, preferably from 100 to 2000 ppm, to match or exceed the oil viscosity of the reservoir under the conditions of a temperature and pressure reservoir. It may be desirable to cross-link the polymer in place in a hydrocarbon-containing formation. In addition, the polymer can be generated on-site in a hydrocarbon-containing formation. Polymers and polymer preparations for use in oil recovery are described in Pat. US. US 6,427,268, 6,439,308, 5,654,261, 5,284,206, 5,199,490 and 5,103,909, the teachings of which are incorporated herein by reference.
    Alkaline compounds An alkaline compound can be included in the aqueous concentrate, 20 normally to increase the pH, decrease the adsorption of surfactants, or achieve optimum salinity. Suitable alkali compounds include alkali metal compounds, for example, alkali metal hydroxides, carbonates, and borates (for example, sodium hydroxide, potassium carbonate, sodium carbonate, sodium bicarbonate, sodium metaborate, sodium tetraborate, and others). 25 Basic organic compounds such as amines (eg, ethanolamine, triethanolamine) and other compounds that can increase pH or neutralize acids present in petroleum can be used instead of the alkali metal compounds indicated above. Organic "alkali" including EDTA, iminosuccinic acid sodium salt, methylglycine diacetate, glutamic acid diacetate, aspartic acid diacetate, hydroxyethylimine diacetate and others of such organic species can also be used. The alkaline compound is normally used in an amount within the range of 0.01 to 5% by weight.
    Oxygen scavengers Suitable oxygen scavengers, usually present in 10 to 500 35 ppm, include, for example, ammonium bisulfite, thiorurea, sodium bisulfite, sodium dithionite, and others, and mixtures thereof.
    In another aspect, the invention relates to an injectable product useful for EOR applications. The injectable product is made by diluting a surfactant or aqueous concentrate composition of the invention with water or brine to a total anionic active level within the range of 0.01 to 5% by weight. As the skilled person appreciates, aqueous surfactants and concentrates can be manufactured, stored and shipped in a variety of concentrated forms for subsequent dilution with water or brine to form an injectable fluid. As a concentrate, the formulation typically contains 15 to 85% by weight of water, 15 to 85% by weight of the inventive surfactant composition, and 0 to 50% by weight of the optional components. The skilled person will recognize that the amounts of water, surfactant composition and optional components employed will depend on salinity, crude oil composition, temperature, the particular formulation, and many other factors. Thus, the knowledgeable person will normally exercise considerable discretion to select appropriate amounts of each component based on the particular set of variables that can be found in a specific oil-bearing formation. The aqueous formulation is typically diluted with water or brine. The resulting injectable product normally contains from 0.01 to 5% by weight, more preferably from 0.05 to 1% by weight, of the surfactant or aqueous concentrate composition.
    In another aspect, the invention relates to a low viscosity, stable oil-in-water microemulsion comprising crude oil, water and a surfactant composition comprising from 10 to 80% by weight of a propoxylated C12-C20 alcohol sulphate, of 10 to 80% by weight of a C12-C20 internal olefin sulfonate, and from 0.1 to 10% by weight of an ethoxylated C4-C12 alcohol sulfate. Traditional viscosity reducers form weak emulsions that remain emulsified under turbulent flow conditions. These compositions do not perform well under reservoir conditions or in a porous medium because of the lack of turbulence. Microemulsions comprising the inventive surfactant compositions have desirable stability even in the absence of turbulent flow conditions.
    In another aspect, the invention involves a method comprising using a surfactant composition comprising from 0.1 to 10% by weight of an ethoxylated C4-C12 alcohol sulfate for enhanced oil recovery. Preferably, the ethoxylated alcohol sulfate is a C6-C10 alcohol sulfate having an average of 2 to 4, more preferably 3, oxyethylene units.
    Although ethoxylated C5-Cn alcohol sulfates are known, they do not appear to have been used in EOR applications. The following examples only illustrate the invention. Those skilled in the art will recognize many variations that are within the spirit of the invention and the scope of the claims. COMPARATIVE EXAMPLE 1
    This comparative example shows a conventional approach in which a cosolvent is used to assist the performance of the surfactant formulation. A surfactant formulation is prepared by combining Petrostep ™ S1, a product made by reacting a Ci6 alcohol with 7 molar equivalents of propylene oxide and sulfating the resulting propoxylated alcohol (1.76 g, 85% active material, product of Stepan Company), Petrostep ™ S2, a Ci5-C18 internal olefin sulfonate (2.27 g, 22% active material, Stepan product), isobutyl alcohol (2.0 g), and tap water (93.96 g). The resulting formulation does not have a concentration of 2% by weight of surfactant. The surfactant formulation is evaluated on phase behavior and viscosity tests highlighted in greater detail below to assess its likely suitability for use in an EOR field test.
    Figs. 1 and 2 illustrate the results of the phase behavior test for this formulation. The values of interfacial tension (IFT) for the formulation are desirably low (<10'3 dynes / cm). However, there are two negative indications of the results. First, the lower IFT region (Fig. 2, NaCI concentration range = 3.9 to 5.6% by weight) corresponds to a narrow range of salinities. Consequently, such a formulation will not be able to deliver a sufficiently low IFT value in the zones of a reservoir for which the water salinity is relatively high. Second, as shown in Fig. 1, at higher salinities (> 5% by weight of NaCI), a gel-like phase forms at the interface between the oil and the surfactant solution. Consequently, at higher salinities, conversion of the microemulsion to a gel could cause blockage in the reservoir. Because both of these results are cause for concern, this surfactant formulation is considered unsuitable for implementation in the field.
    Microemulsion viscosity results (Fig. 3) raise additional concerns about the comparative formulation. At salinity of 3.78% of total dissolved solids (TDS) or more, there is a substantial and unexpected temperature dependence on viscosity. In particular, the microemulsion viscosity increases significantly at higher temperatures. This also results in rendering the formulation unsuitable for field testing.
    EXAMPLE 2 This inventive example eliminates the cosolvent while providing superior performance of the surfactant formulation. A surfactant formulation is prepared by combining Petrostep ™ S13C, a product made by reacting a C13 alcohol with 7 molar equivalents of propylene oxide and sulfating the resulting propoxylated alcohol (0.49 g, 85% active material, product of Stepan), Petrostep ™ S2 (1.18 g, 22% active material, Stepan product), Petrostep CS-207, a product made by reacting a C6-C10 alcohol with 3 molar equivalents of ethylene oxide and sulfating the alcohol resulting ethoxylate (0.04 g, 58% active material, Stepan product), and tap water (98.29 g). The resulting formulation, which has a concentration of 0.7% by weight of surfactant, is evaluated in phase behavior and viscosity tests to assess its suitability for use in an EOR field test.
    Results of the phase behavior test appear in Fig. 4. The upper image shows that no gel phase forms at the interface between the oil and surfactant solution, even at relatively high salinity. Additionally, as shown in the ratio of solubilization versus TDS plot, the formulation provides a low IFT region over a much greater range of salinity (all salinities greater than 4.6% by weight of TDS). Thus, the results of phase behavior are favorable.
    Microemulsion viscosity data (Figs. 5 and 6) show that viscosity is relatively insensitive to changes in temperature over a wide range of salinities. The increase in viscosity at very high salinity (5.59% TDS or 90% produced water) is acceptable because it is only that which the reservoir would see such as high salinity. In conclusion, this formulation deserves further evaluation and potential field implementation. Phase Behavior Test Procedure The procedure outlined below is adapted from that published by Adam K. Flaaten in an M.S.E. excellent entitled, “Experimental Study of Microemulsion Characterization and Optimization in Enhanced Oil Recovery: A Design Approach for Reservoirs with High Salinity and Hardness” (“experimental study of microemulsion characterization and optimization in enhanced oil recovery: A Design Approach for Reservoirs with High Salinity and Hardness ") (see, esp. Pp. 23-31). 1. Pipette Preparation
    A phase behavior experiment involves mixing certain proportions of a chemical ASP solution (sometimes just surfactant, sometimes alkali and surfactant), saline water, and crude oil in a pipette array. The pipettes used are usually 10 mL of borosilicate pipettes with the bottom sealed by a flame torch. The pipette arrangement serves to create a gradient of salinity, where different volumes of saline water are added to each pipette to give different salinities. In addition, equal volumes of aqueous chemical ASP solution are added to each pipette, with that ASP solution having a fixed concentration of surfactant, co-surfactant, cosolvent, polymer and / or alkali. 2.Addition Order
    Stock solutions added to the pipettes have concentrations several times that of the final target concentration and present a risk of not mixing in an appropriate order. Contact of the concentrated electrolyte stock with the surfactant stock could adversely affect performance, that is, it could cause permanent precipitation. To minimize this risk, the stock of surfactants is added first, followed by fresh water and then produced water. Crude oil is the last component added after the aqueous stability is verified and fluid levels are recorded. 3. Aqueous Stability and Initial Readings
    Before adding crude oil to the pipettes, an aqueous stability checks the need to be made for clarity and homogeneity of all aqueous mixtures. The objective of the aqueous stability test is to determine the compatibility of the surfactants with electrolytes, and to ensure a stable surfactant slug that will not carry out a separate phase or contain precipitates before the core flood or field injection. As a quick scan during the phase behavior test, aqueous fluids are stirred after being dispensed into pipettes, and then allowed to settle for an hour or more. The fluids in the phase behavior arrangement are visually inspected, and the salinity is recorded in which turbidity and / or phase separation takes place. After this initial scan, the mixtures are studied in a more detailed aqueous stability test where larger volumes containing polymer are evaluated in glass bottles if a formulation is chosen for further testing. A surfactant / polymer / electrolyte mixture that is injected into the core or reservoir rock must be a clear, single-phase mixture. 4. Sealing and mixing
    After assessing aqueous stability and adding crude oil, the pipette tips are heat sealed with a flame torch. After heat sealing, the pipettes are allowed to cool before being slowly inverted 3 times to allow the petroleum and aqueous phases to mix. Slow inversion generates a microemulsion without producing foam. Generation of 10 microemulsion of oil and aqueous phases will yield a thermodynamically stable oil-in-water, water-in-oil and bicontinuous micro-emulsion phase and its analysis is the objective of the phase behavior experiment. 5. Measurements and Observations
    Prepared pipettes not kept in an oven at a specified reservoir temperature in the field for the duration of the phase behavior experiment. The visual and quantitative evaluation of the miscroemulsion properties and interfaces are recorded 1, 2, 3, 5, 7, 10, 14, 21, 30, and 60 days after the pipettes are mixed. 20 6. Visual Assessment
    A qualitative, visual inspection of the pipettes is used to assess the presence of gels or macroemulsion, the fluidity of interfaces, and the viscosity of the microemulsion. Gel and / or other highly viscous phases can cause rock clogging, high surfactant retention, and other problems and thus should be avoided, if possible. Careful observation of drop size and behavior when pipettes are gently mixed can be used to indicate interfacial activity. In a good formulation, the water-oil mixture at optimal salinity takes a long time to separate after mixing. Most of it also shows a uniform brown or gray color. 30 7. Quantitative Evaluation
    Pipettes that are free of gels and macroemulsion and have free flow interfaces are quantified to calculate phase volumes. Measurements of levels of aqueous / microemulsion and / or microemulsion / oil interface are interpolated to the nearest 0.01 ml using the markings on the pipette. From these 35 interface measurements, the volumes of each phase (oil, water and microemulsion) and the partial volumes of oil and water phases present in the microemulsion can be calculated. In addition, analysis and comparison of these volumes and volume fractions with respect to salinity and time helps to determine optimal salinity, optimal solubilization ratio and coalescence properties of the microemulsion. Based on these data, solubilization ratio versus 5 salinity curves are drawn. 8. Types of microemulsion
    The interaction of an aqueous phase containing surfactant with the hydrocarbon phase will, under some conditions, produce a microemulsion containing surfactant, water and oil and this microemulsion has been a focal point for chemical EOR research. Windsor characterized these microemulsions as Type I, Type II, and Type III.
    Type I refers to an oil-in-water microemulsion in which a portion of the oil has been solubilized by the surfactant in water. In contrast, Type II defines a water-in-oil microemulsion in which a portion of water has been solubilized by the surfactant in oil. In a Type III microemulsion, oil and water are both solubilized by the surfactant, which equilibrates with excess oil and water phases. This microemulsion can have varying proportions of oil and water and is assumed to contain essentially all of the surfactant originally in the aqueous phase. All microemulsions are thermodynamically stable by definition, and in theory, will not separate into oil and water constituents. 9. Microemulsion characterization
    Phase behavior microemulsions can be characterized using several different methods. These methods evaluate to relate 25 proportions of oil and water solubilization, coalescence time, interfacial tension between fluid phases, viscosity and conductivity, with the most common method that evaluates solubilized oil and water. Healy et al. He developed a method to graph the oil and water solubilized in the microemulsion. For each salinity, the volumes of oil (Vo) and water (Vw) 30 contained in the microemulsion are measured first. The volumes are then normalized to the total volume of the pure surfactant (Vs) to obtain oil and water solubilization ratio values (V0 / Vs and Vw / Vs, respectively). The solubilization ratios are then plotted for each salinity and subsequently fitted with curves to form solubilization curves. The intersection of oil and water solubilization ratio curves is defined as the optimal solubilization ratio and optimal salinity (variables such as temperature can be used other than salinity). 10. Solubilization Reason
    Original oil and water volumes are known from the aqueous and oil interface readings, and changes in the microemulsion interfaces after mixing can determine volumes of oil and water present in the microemulsion. Solubilization ratios for both oil and water can be calculated for each salinity and subsequently plotted to determine trends in the data. 11. Oil solubilization ratio
    Oil solubilization ratio is the volume of oil present in a microemulsion per volume of total active surfactant originally dispensed in the pipette. The basic equation is:
    where SR0 is the oil solubilization ratio, it is the volume of oil present in the microemulsion, and VSUrf is the volume of total surfactant present in the pipette. All surfactant is assumed to be in the microemulsion and only surfactant is used in the calculation. 12. Water solubilization ratio
    Water solubilization ratio is the volume of water present in a microemulsion per volume of total surfactant originally dispensed in the pipette. The basic equation is:
    where SRW is the water solubilization ratio, V2 is the volume of water present in the microemulsion, and Vsurf is the volume of total surfactant present in the pipette.
    Fig. 7 illustrates results of a phase behavior test. Tubes 1 to 5 contain a Type I “oil in water” microemulsion, tube 10 has a Type II microemulsion of “water in oil”, and tubes 6 through 9 have a Type III microemulsion consisting of three phases. The following volume measurements are made using an ultraviolet lamp, which helps to distinguish the different phases.
    Taking tube 6 as an example (see Fig. 8), the initial water-oil interface before mixing is located in the dashed line on the pipette (2.04 cm3). After mixing and stabilizing, the three phases are separated by two solid lines in the figure.
    The volume of the water phase decreased from 2.04 cm3 to 1.70 cm3 (V2 = 0.34 cm3), the volume of the oil phase decreased by 0.10 cm3 (Vi = 0.10 cm3), and the microemulsion phase formed again has a volume of 0.44 cm3 (Vi + V2). The solubilization of oil and water is defined as follows:

    Vsurf is the total volume of the surfactant added to the tube, Vw is the total aqueous volume in the tube (2.04 cm3 here), and Csurf is the surfactant concentration (1%). 13. Optimal Solubilization Ratio and Salinity
    The optimal solubilization ratio is the ratio at which the oil and water solubilization values are the same for the same microemulsion. The corresponding salinity value in the optimal solubilization ratio is called optimal salinity, and microemulsions in this optimum bridge are bicontinuous, Type III microemulsions. The solubilization ratio is a function of salinity. 14. Chun Huh correlation
    The addition of surfactant reduces the interfacial tension (IFT) between oil and water, and this reduction in IFT is the mechanism of interest for mobilizing residual oil in chemical EOR. In a pipette containing a Type I microemulsion, the IFT of interest is between the microemulsion and oil phases. The IFT of this microemulsion / oil interface decreases as the salinity is increased into the Type III region until the interface disappears at the Type lll / Type salinity limit. Similarly, a pipette containing a Type II microemulsion will have an aqueous / microemulsion interface and the IFT decreases as the salinity is decreased within the Type III region. Both the aqueous / microemulsion and microemulsion / oil interfaces exist in a Type III environment, and the IFTs of these two interfaces are equal in optimal salinity. Determination of this IFT value at optimal salinity is important for surfactant selection and performance. Huh derived a theoretical relationship between solubilization ratio and IFT at optimal salinity. Huh's equation gives a good estimate of IFT over a wide range of salinity and other variables for a large number of oils including crude oils.
    Chun Huh correlation:
    where y is the IFT in dyne / cm, C is a constant, which is normally 0.3 dyne / cm, and o is the solubilization ratio. The previous examples are considered as illustrations only. The following claims define the invention.
    权利要求:
    Claims (9)
    [0001]
    1. Surfactant composition, useful for improved oil recovery, characterized by the fact that it comprises: (a) 10 to 80% by weight of a propoxylated C12-C14 alcohol sulfate having an average of 6 to 8 oxypropylene units or alcohol sulfate C16-C18 having an average of 6 to oxypropylene units; (b) from 10 to 80% by weight of a C15-C18 internal olefin sulfonate; and (c) from 1 to 5% by weight of an ethoxylated C6-C10 alcohol sulfate having an average of 2 to 6 oxyethylene units.
    [0002]
    2. Composition according to claim 1, characterized by the fact that it comprises from 10 to 40% by weight of propoxylated alcohol sulfate, and 50 to 80% by weight of internal olefin sulfonate.
    [0003]
    3. Composition according to claim 1, characterized by the fact that from 20 to 30% by weight of propoxylated alcohol sulfate, from 60 to 75% by weight of internal olefin sulfonate, and from 2 to 4% by weight ethoxylated alcohol sulphate.
    [0004]
    4. Aqueous concentrate useful for oil recovery, characterized by the fact that it comprises: (a) water; and (b) the surfactant composition as defined in claim 1.
    [0005]
    5. Concentrate according to claim 4, characterized by the fact that it comprises from 15 to 85% by weight of water, from 15 to 85% by weight of the surfactant composition, and from 0 to 50% by weight of one or more additives selected from the group consisting of co-surfactants, co-solvents, polymers, alkaline compounds, oxygen scavengers, and mixtures thereof.
    [0006]
    6. Injectable product, characterized by the fact that it is made by diluting the surfactant composition as defined in claim 1, with water or brine to a total anionic active level within the range of 0.01 to 5% by weight.
    [0007]
    7. Injectable product characterized by the fact that it is made by diluting the concentrate as defined in claim 4, with water or brine to a level of total anionic assets within the range of 0.01 to 5% by weight.
    [0008]
    8. Microemulsion of oil in water of low viscosity, stable, characterized by the fact that it comprises crude oil, water and the surfactant composition as defined in claim 1.
    [0009]
    9. Surfactant composition, useful for improved oil recovery 5, characterized by the fact that it comprises: (a) 10 to 40% by weight of a propoxylated C12-C14 alcohol sulfate having an average of 6 to 8 oxypropylene units or a C16-C18 alcohol sulfate with an average of 6 to 8 oxypropylene units; (b) 50 to 80% by weight of a C15-C18 internal olefin sulfonate; and 10 (c) from 1 to 5% by weight of a C6-C10 ethoxylated alcohol sulphate having an average of 2 to 6 oxyethylene units.
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    法律状态:
    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|
    2020-12-08| 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 14/05/2012, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US201161486535P| true| 2011-05-16|2011-05-16|
    US61/486,535|2011-05-16|
    PCT/US2012/037842|WO2012158645A1|2011-05-16|2012-05-14|Surfactants for enhanced oil recovery|
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