WO2011071747A1 - Tensioactifs à faible tension interfaciale pour des applications dans le pétrole - Google Patents

Tensioactifs à faible tension interfaciale pour des applications dans le pétrole Download PDF

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Publication number
WO2011071747A1
WO2011071747A1 PCT/US2010/058729 US2010058729W WO2011071747A1 WO 2011071747 A1 WO2011071747 A1 WO 2011071747A1 US 2010058729 W US2010058729 W US 2010058729W WO 2011071747 A1 WO2011071747 A1 WO 2011071747A1
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compound
oil
group
alkyl
formula
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PCT/US2010/058729
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English (en)
Inventor
David Soane
Rosa Casado Portilla
John H. Dise
Robert P. Mahoney
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Soane Energy, Llc
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Priority to CA2783831A priority Critical patent/CA2783831C/fr
Priority to EP10836443.1A priority patent/EP2510080A4/fr
Priority to BR112012014008A priority patent/BR112012014008A2/pt
Priority to AU2010328497A priority patent/AU2010328497B2/en
Publication of WO2011071747A1 publication Critical patent/WO2011071747A1/fr

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    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
    • C10G1/04—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
    • C10G1/045—Separation of insoluble materials
    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C217/00—Compounds containing amino and etherified hydroxy groups bound to the same carbon skeleton
    • C07C217/02—Compounds containing amino and etherified hydroxy groups bound to the same carbon skeleton having etherified hydroxy groups and amino groups bound to acyclic carbon atoms of the same carbon skeleton
    • C07C217/04—Compounds containing amino and etherified hydroxy groups bound to the same carbon skeleton having etherified hydroxy groups and amino groups bound to acyclic carbon atoms of the same carbon skeleton the carbon skeleton being acyclic and saturated
    • C07C217/28—Compounds containing amino and etherified hydroxy groups bound to the same carbon skeleton having etherified hydroxy groups and amino groups bound to acyclic carbon atoms of the same carbon skeleton the carbon skeleton being acyclic and saturated having one amino group and at least two singly-bound oxygen atoms, with at least one being part of an etherified hydroxy group, bound to the carbon skeleton, e.g. ethers of polyhydroxy amines
    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C235/00—Carboxylic acid amides, the carbon skeleton of the acid part being further substituted by oxygen atoms
    • C07C235/70—Carboxylic acid amides, the carbon skeleton of the acid part being further substituted by oxygen atoms having carbon atoms of carboxamide groups and doubly-bound oxygen atoms bound to the same carbon skeleton
    • C07C235/72—Carboxylic acid amides, the carbon skeleton of the acid part being further substituted by oxygen atoms having carbon atoms of carboxamide groups and doubly-bound oxygen atoms bound to the same carbon skeleton with the carbon atoms of the carboxamide groups bound to acyclic carbon atoms
    • C07C235/76—Carboxylic acid amides, the carbon skeleton of the acid part being further substituted by oxygen atoms having carbon atoms of carboxamide groups and doubly-bound oxygen atoms bound to the same carbon skeleton with the carbon atoms of the carboxamide groups bound to acyclic carbon atoms of an unsaturated carbon skeleton
    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C235/00—Carboxylic acid amides, the carbon skeleton of the acid part being further substituted by oxygen atoms
    • C07C235/70—Carboxylic acid amides, the carbon skeleton of the acid part being further substituted by oxygen atoms having carbon atoms of carboxamide groups and doubly-bound oxygen atoms bound to the same carbon skeleton
    • C07C235/84—Carboxylic acid amides, the carbon skeleton of the acid part being further substituted by oxygen atoms having carbon atoms of carboxamide groups and doubly-bound oxygen atoms bound to the same carbon skeleton with the carbon atom of at least one of the carboxamide groups bound to a carbon atom of a six-membered aromatic ring
    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C69/00—Esters of carboxylic acids; Esters of carbonic or haloformic acids
    • C07C69/52—Esters of acyclic unsaturated carboxylic acids having the esterified carboxyl group bound to an acyclic carbon atom
    • C07C69/593—Dicarboxylic acid esters having only one carbon-to-carbon double bond
    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C69/00—Esters of carboxylic acids; Esters of carbonic or haloformic acids
    • C07C69/612—Esters of carboxylic acids having a carboxyl group bound to an acyclic carbon atom and having a six-membered aromatic ring in the acid moiety
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
    • C09K8/524—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
    • C09K8/584—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/602—Compositions for stimulating production by acting on the underground formation containing surfactants
    • C09K8/604—Polymeric surfactants
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
    • C10G1/04—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
    • C10G1/047—Hot water or cold water extraction processes
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G21/00—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents
    • C10G21/06—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents characterised by the solvent used
    • C10G21/12—Organic compounds only
    • C10G21/16—Oxygen-containing compounds
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G21/00—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents
    • C10G21/06—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents characterised by the solvent used
    • C10G21/12—Organic compounds only
    • C10G21/20—Nitrogen-containing compounds
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G31/00—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for
    • C10G31/08—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for by treating with water
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/20—Characteristics of the feedstock or the products
    • C10G2300/201—Impurities
    • C10G2300/205—Metal content
    • C10G2300/206—Asphaltenes

Definitions

  • the application relates generally to surfactants useful for petroleum applications.
  • the properties of crude oil also contribute to the difficulty of environmental remediation following, for example, an oil spill onto a body of water.
  • the high interfacial tension causes the oil to float on the water and adhere to plants, animals and soil.
  • the aromatic constituents of the oil evaporate, the heavier residues can sink, contaminating the subsurface structures.
  • Current treatment of spilled oil on water surfaces relies on time- consuming and expensive biological degradation of the oil.
  • Thick, adherent crude oil cause environmental problems in the oil fields as well. Oil deposits attached to vehicles and equipment must be cleansed with jets of hot water and caustics.
  • the viscosity of heavy crude oil makes the substance difficult and expensive to transport to upgrading facilities.
  • Crude oil as it is produced, is typically associated with connate water that can form a stable emulsion with the oil in multiple phases, including solid-in-oil dispersions, water-in-oil emulsions, and oil-in-water-in-oil emulsions.
  • Certain hydrocarbon molecules found in heavy crude oils can act as emulsifiers to stabilize the various species of water plus oil emulsions.
  • asphaltenes and high naphthenic acids along with submicron sized solid particles such as silica, clay or other minerals, can stabilize emulsions such as water-in-oil emulsions where the heavy crude oil fluid comprises the continuous phase.
  • Asphaltenes are high-molecular weight, complex aromatic ring structures that can also contain oxygen, nitrogen, sulfur or heavy metals. As polar molecules, they tend to bond to charged surfaces, especially clays, leading to formation plugging and oil wetting of formations. Asphaltenes tend to be colloidally dispersed in crude oils, stabilized by oil resins.
  • Asphaltenes, paraffmic waxes, resins and other high-molecular-weight components of heavy crude exist in a polydisperse balance within the heavy crude fluid.
  • a change in the temperature, pressure or composition can destabilize the polydisperse crude oil.
  • the heavy and/or polar fractions can separate from the oil mixture into steric colloids, micelles, a separate liquid phase, and/or into a solid precipitate.
  • the asphaltene micelles can be destabilized during well treatments, e.g., acidizing or condensate treatments, leading to asphaltene precipitation. Asphaltene precipitation causes problems all along the crude oil process.
  • crude oil e.g., asphaltenes and naphthenic acids
  • these components can precipitate out of the crude oil itself and lodge at the bottom of a storage vessel or tank to form a viscous, tarry sludge.
  • These components also become available as emulsifying agents to sustain water-in-oil emulsions.
  • the emulsion layer has a higher density than light crude, so that it tends to sink to the bottom of storage vessels along with the heavy oil components and associated clay/mineral solids, contributing to the buildup of oil sludge, a thick waste material formed from the various deposits sedimenting out from a crude oil mixture.
  • sludge forms when heavier components of crude oil separate from the liquid hydrocarbon fractions by gravity and sink to the bottom of the vessel.
  • Components of the sludge can include usable hydrocarbons along with the aforesaid entrained water as a water-in-oil emulsion, along with a multitude or organic and inorganic components and contaminants.
  • the sludge becomes increasingly viscous over time. Any given storage vessel can thus contain a significant amount of sludge, which can diminish storage space for useful crude oil and which can otherwise reduce the efficiency of storage tank operation. Sludge may also require removal if the storage vessel is to be maintained, repaired or inspected.
  • surfactant-based approaches aqueous solutions are used to treat the sludge and coalesce the water droplets emulsified within the oil matrix.
  • the particular surfactant is designed to overwhelm the surface energy that is created by the asphaltene/naphthenic acid molecules and return the aqueous portion to a more-native interfacial tension with organics.
  • Current surfactant additives have been shown effective but have commercial limitations because of either high dosage requirements or ineffective solids interactions.
  • Solvent systems typically use a mixture of known aromatic and aliphatic-based organics to decrease the viscosity of the heavier oil fractions and cause phase separation. Issues of cost and toxicity, however, have been raised with the use of solvent-based approaches.
  • drilling mud a drilling fluid
  • the clean drilling mud is injected through a series of pipes called the drill string to reach the bit, and then flows back up to the surface in the annular area between the drill string and the inside of the wellbore carrying the cuttings and other particulate matter.
  • the drilling mud can be water-based or oil-based.
  • Oil-based drilling fluids include as their base material any of a number of natural or synthetic oils, including petroleum fractions, synthetic compounds, blends of natural and synthetic oils, along with a variety of performance-enhancing additives.
  • the wellbore annulus must be cleaned to remove drilling fluids, gelled drilling fluid, residual additives from drilling fluids, and the like.
  • One cleaning process can take place before the casing and cementing operations are done, and another cleaning process is done after the casing is installed.
  • the casing must be cleaned to a water-wet condition with no oil sheen.
  • Oil-based drilling fluids, especially synthetic based muds (SBMs) are particularly difficult to remove from the surfaces they contact.
  • oil-based fluids can form invert emulsions upon contact with water, where the continuous phase is predominantly organic, and the discontinuous phase is aqueous. This emulsion will tenaciously coat any surface that it contacts, leading to oil wetting of borehole surfaces, casing surfaces, and the surfaces of other equipment that it contacts.
  • Wellbore cleaning can involve the use of a sequence of fluids, each having a specific purpose.
  • formulations are selected that give maximum performance while using minimum amounts of material.
  • the fluids must be chemically and physically compatible, so that an earlier one does not interfere with the function of subsequent ones. Cleaning operations must be conducted carefully, so that the clay components of the drilling mud residue do not come into contact with water, thereby forming a thick paste that adds to the difficulty of removal.
  • a cleaning system that is effective and efficient in removing drilling mud films and residua from wellbore surfaces. This need is exacerbated by the prevalence of SBMs, which produce harder-to-remove films.
  • the invention relates to the discovery to surfactant compounds with utility in recovering or extracting oil, such as fossil fuels.
  • the invention relates to a compound having the Formula (I):
  • A is an alkyl, alkenyl, alkadienyl, alkynyl, cycloalkyl, or cycloalkenyl, each optionally substituted;
  • p is 1 or 2; preferably 2;
  • n and n are independently 0, 1, 2, 3, 4, or 5;
  • each of Gi and G 2 are independently absent, O, S, NR 2 , (CO)O, O(CO), CO, CONR 2 , or NR 2 CO;
  • each R 2 is independently H or a lower alkyl
  • G 3 is absent, (CH 2 ) q or d;
  • q 1, 2, 3, 4 or 5;
  • R is a hydrophilic group
  • Ri is a saturated or unsaturated hydrophobic aliphatic group.
  • m is 1 or 2 and n is 0 or 1.
  • at least one of Gi and G 2 are present.
  • the invention is compound having the Formula (la):
  • the invention is directed to a compound of Formula (II):
  • D is an aliphatic polymer
  • p is 1 or 2; preferably 2;
  • n and n are independently 0, 1, 2, 3, 4, or 5;
  • each of Gi and G 2 are independently absent, O, S, NR 2 , (CO)O, O(CO), CO, CONR 2 , or NR 2 CO;
  • each R 2 is independently H or a lower alkyl
  • G 3 is absent, (CH 2 ) q or Gi;
  • q 1, 2, 3, 4 or 5;
  • R is a hydrophilic group
  • Ri is a saturated or unsaturated hydrophobic aliphatic group.
  • the invention encompasses a compound having the Formula (Ila);
  • t is 0 or 1 ;
  • G 4 is O or NH; and D and Ri are as defined above.
  • E is alkyl, alkenyl, alkadienyl, alkynyl, cycloalkyl, cycloalkenyl, aryl and heteroaryl;
  • G 5 is CONH;
  • D 2 is a hydrophilic aliphatic polymer
  • p 1 or 2.
  • the invention encompasses a compound having the Formula (IV):
  • each J is independently selected from the group consisting of hydrogen and Fragment (A) having the structure shown below;
  • E is a hydrophobic group selected from the group consisting of alkyl, alkenyl, alkadienyl, alkynyl, cycloalkyl, cycloalkenyl, aryl and heteroaryl; and wherein at least J is the Fragment (A).
  • the invention also encompasses a compound having the Formula (V):
  • D 2 is a hydrophilic aliphatic polymer
  • each J is independently selected from the group consisting of H and the Fragment (A):
  • E is a hydrophobic group selected from the group consisting of alkyl, alkenyl, alkadienyl, alkynyl, cycloalkyl, cycloalkenyl, aryl and heteroaryl;
  • the invention also relates to methods for extracting oil from an oil mixture comprising:
  • An oil mixture is a mixture comprising oil and at least one other component.
  • the oil mixture can comprise oil sands, waterborne oil slicks or oil deposits.
  • the methods of the invention can comprise the additional steps of adding water or transporting the mixture via a pipeline.
  • the compounds and compositions of the invention can be used in methods of degreasing machinery, such as those used in oil or bitumen production.
  • Figure 1 shows comparison photographs of phase separation.
  • Figure 2 shows comparison photographs of solutions prepared at neutral and acidic pH.
  • compositions, systems and methods related to ultra-low interfacial tension (“IFT") surfactants for applications in the petroleum industry are based on the discovery that multiple aliphatic-based functionalities can be incorporated onto a single surfactant molecule.
  • This molecule can include functionality that allows it to be either surface-active or surface- inactive by adjusting or "tuning" the surfactant by means of an adjustment of a parameter such as temperature or pH.
  • the application of a single-molecule, switchable surfactant system is prepared in aqueous solution. Suitable surfactant solutions for application in enhanced oil recovery will also display very low interfacial tension values with both crude oil as well as organics with aliphatic and aromatic character.
  • surfactant solutions exhibiting only pH switchability will remain in solution at elevated temperatures, so that they can be inserted into underground wells, where temperatures may range between 70-100°C.
  • the ability to deactivate a surfactant would enable the user first to create an emulsion of the petroleum to be recovered, then to transport the oil in an emulsified state, then to easily separate the oil from the emulsion when it has reached its desired destination. Controlling the phase state of an oil deposit could potentially be a useful tool in recovering difficult to access, yet desirable, sources of oil.
  • compositions of particular use in these systems and methods can include at least one compound of the Formula (I), Formula (la), Formula (II), Formula (Ila), Formula (III), Formula (IV) or Formula (V) as described above.
  • the compound has the Formula (I), (la), (II) or (Ila).
  • the invention encompasses compounds having the Formula (I) or Formula (la), wherein A is an alkyl (e.g., a C3-C8 alkyl) or cycloalkyl, each optionally substituted. In another embodiment, A is an alkyl-substituted cyclopentyl or cyclohexyl.
  • alkyl-substituted cyclohexyl is propylcyclohexyl and ethylcyclohexyl.
  • the compound has the Formula (I), wherein Gi is selected from the group consisting of O, S, NR 2 , C(0)0, OC(O), C(O), C(0)NR 2 and NR 2 C(0).
  • the compound has the Formula (I), wherein Gi is selected from the group consisting of C(0)0, OC(O), C(O), C(0)NR 2 and NR 2 C(0).
  • Gi is selected from C(0)0 and C(0)NR 2 .
  • the compound has the Formula (I) wherein p is 1.
  • the compound has the Formula (I) wherein p is 2.
  • the invention is a compound of Formula (I) wherein m is 1 or 2.
  • the invention is a compound of Formula (I), wherein n is 0 or 1.
  • the invention is a compound of Formula (I), wherein R is C(0)OH.
  • the invention is a compound of Formula (I), wherein Ri is selected from the group consisting of C 5 -C 2 o alkyl, C 5 -C 2 o alkenyl, and C 5 -C 2 o alkadienyl.
  • the compound has the Formula (II) or (Ila), wherein D is selected from the group consisting of polyethylene glycol, poly(ethylene glycol), poly(ethylene glycol), and
  • glycol /poly(propylene glycol) copolymers, polyethylene glycol methyl ether,
  • the compound has the Formula (II), wherein p is 1. In a further aspect, the compound has the Formula (II), wherein p is 2. In yet an additional aspect, the compound has the Formula (II), wherein m is 1 or 2, or n is independently 0 or 1, or a combination thereof.
  • the invention also includes the compound of Formula (II), wherein each Gi is independently OC(O), C(0)0, C(O), C(0)NR 2 or NR 2 C(0). In an additional aspect, the compound has the Formula (II) wherein G 2 is absent. In a further aspect, the compound has the Formula (II) wherein R is C(0)OH.
  • compounds of Formula (I), (la), (II) and (Ila) comprise a hydrophilic portion (substituent R) and a hydrophobic aliphatic group (substituent Ri).
  • the aliphatic groups include saturated or unsaturated carbon chains, preferably between five and twenty units in length, or five and eighteen units in length, or eight and twenty units in length, or hydrogen.
  • the carbon chains can optionally be unsaturated and, when present, reside anywhere along the carbon chain.
  • the hydrophilic portion of the inventive compounds can comprise one or more hydrophilic groups or substituents.
  • Hydrophilic portions or groups can be an ionizable groups, including, for example, amines and carboxylic acids.
  • the hydrophilic group is C(0)OH.
  • Hydrophilic groups also include hydrophilic polymers, including, but not limited to, polyalkylamine, poly(ethylene glycol) or poly(ethylene
  • Nonionic hydrophilic materials such as polyalkylamine, poly(ethylene glycol) or poly(ethylene glycol)/poly(propylene glycol) copolymers can be used to increase hydrophilicity or aid stability in salt solutions.
  • the surfactant compound has the Formula (III).
  • D 2 is a polymer or copolymer containing ether groups.
  • the invention also encompasses a method for the preparation of a compound having the Formula (III) comprising reacting an aliphatic or aromatic diacid with a polyetheramine.
  • the compound has the Formula (III), wherein E is Ci-C 6 alkyl.
  • the surfactant compound has the Formula (IV) or Formula (V) as described above, wherein D 2 is a polyether.
  • D 2 is a polyether.
  • E is a C 5 - C 2 o alkyl, C 5 -C 2 o alkadienyl or C 5 -C 2 o alkenyl.
  • the invention also is directed to methods for the preparation of a compound having Formula (IV) or Formula (V) comprising reacting an amino-containing polyether with an epoxy-containing compound.
  • An example of an amino-containing polyether is a polyetheramine.
  • Non-limiting examples of epoxy-containing compounds are styrene oxide, 2,3-diphenyloxirane, phenyl glycidyl ether, 1-naphthyl 2-oxiranylmethyl ether, and poly[(o-cresyl glycidyl ether)-co-formaldehyde.
  • a lower alkyl is a Ci-Ci 0 alkyl, Ci-C 6 alkyl, or C1-C4 alkyl
  • the compounds described herein can be used as surfactants. In embodiments, these compounds can demonstrate switchable behavior under conditions where pH and/or temperature is varied.
  • the inventive surfactants such as a compound of Formula (I), (la), (II), (Ila), (III), (IV) or (V), can demonstrate switchable behavior based on pH, where the surfactant is capable of sustaining an emulsion at a higher pH, but loses its
  • pH switchable surfactants can comprise an ionizable group and a hydrophobic portion, or an ionizable portion and a hydrophilic and a hydrophobic portion.
  • the ionizable group on the surfactant reacts to changes in pH that impact its emulsification properties. For example, with a decrease in pH, the ionizable group will be in the protonated form and the surfactant molecule will lose its solubility in water solution, thereby losing its emulsification properties.
  • the ionizable group will be in the ionic form and the surfactant molecule will increase its solubility in water solution, thus being capable of sustaining emulsions of oil in water.
  • This behavior is reversible because no functional groups are cleaved in the process.
  • Non-limiting examples of surfactants demonstrating this behavior include surfactants prepared in accordance with Examples 1 , 2 and 3 shown below.
  • surfactants can demonstrate switchable behavior based on changes in temperature, whereby they are able to stabilize emulsions at temperatures below their cloud points but lose their emulsification properties at temperatures above their cloud points.
  • temperature switchable surfactants will have a hydrophobic portion and a hydrophilic portion mainly containing, for example, ethoxylated groups.
  • Such surfactants can display solubility in water solutions at temperatures below the cloud point and will be able to emulsify oil in water. However, upon increasing the temperature above the cloud point, the surfactants will lose solubility in water solutions and will lose their emulsification properties. The behavior is reversible because no functional groups are cleaved in the process.
  • Non-limiting examples of surfactants demonstrating this behavior are those prepared in accordance with Examples 9, 10, 11 and 13.
  • surfactants can demonstrate switchable behavior based on changes in temperature and pH. There are trigger points for emulsification capability that are determined by pH and by temperature. Non-limiting examples of such surfactants are those prepared in accordance with Examples 4, 5, 6 and 7 below.
  • temperature switchable behavior can be elicited in compounds having ether groups.
  • PEG or hydroxyl-terminated ethers such as PPO and PEO (e.g., Pluronics) can be reacted with anhydrides such as alkene succinic anhydride (8, 9, 12 units), and styrene maleic anhydride copolymers.
  • the hydrophilic portion of the surfactant compounds of the invention include one or more polymers or copolymers containing ether groups. These polymers impart the compounds with a cloud point. The compounds will display solubility in water at temperatures below the cloud point and, as a consequence, are able to emulsify oil. However, upon increasing the temperature over the cloud point, the compounds become less soluble in water and show a decrease in emulsification properties. It is believed that this behavior is reversible because no functional groups are cleaved in the process.
  • amino-containing compounds are: polyetheramines, such as JEFF AMINES® from Huntsman, and other PEG and PPO/PEG containing primary, secondary amines.
  • epoxy compounds include aryl glycidyl ether, such as: styrene oxide, 2,3-diphenyloxirane, phenyl glycidyl ether, 1-naphthyl 2-oxiranylmethyl ether, and poly[(o-cresyl glycidyl ether)-co-formaldehyde;
  • Acid groups with amines or alcohols include reacting aromatic diacids with a polyether containing (primary or secondary) amine or hydroxy units.
  • Another embodiment is the reaction of a polyethylene glycol-diacid terminated with and aromatic amine or alcohol;
  • the hydrophilic portion of compounds of the invention is a combination of (i) one or more copolymers containing ether groups and (ii) one or more ionizable carboxylic acid groups.
  • the obtained compound has emulsification capabilities that are triggered by a change in pH or temperature. Below a specific pH, the surfactant compound has emulsification properties under certain temperature conditions. However, above that pH, the temperature at which the surfactant has emulsification properties increases. The surfactants are thus tunable based on changes in pH or temperature.
  • Exemplary surfactants can be synthesized by reacting:
  • PEG and PPO/PEG are the PLURONICS®.
  • aromatic anhydrides are phenyl succinic anhydride;
  • surfactants can be suitable for applications where undesired petroleum products pose an environmental problem. Oil cleanup using surfactants may be required for two different types of contamination.
  • the surfactant family can be used on waterborne slicks, acting as a dispersing agent. It will act to disperse the oil into the water body itself and encourage biodegradation through natural decomposition means.
  • a solution of surfactant can be used to remove physiosorbed crude or refined oils from inorganic rocks, sand, or other substrates as an emulsion.
  • Oil sands comprise heavy petroleum products coating sand and clay, an assemblage that is similar to certain artificial composites that are formed during a man- made oil spill, as described above.
  • the surfactant compounds and compositions thereof described herein may be useful for extracting bitumen from the other components of the tar sands material.
  • mined oil sands are extracted using hot water, a process that causes the less dense bitumen to flow off the sand and float to the surface of a settling tank. This so-called "primary froth" is contaminated with various materials derived from the mined products (solid particles, clay, and sand).
  • inventive surfactants in accordance with these systems and methods may further be applied to other aspects of the extraction process, for example in the oil sands strip mining or in-situ operations, where the ability to emulsify the petroleum component of the oil sands ore may enhance the efficiency or economy of separating the bitumen from the insoluble byproducts.
  • Transporting petroleum precursors for further processing is a necessary, though expensive, part of obtaining usable crude oil.
  • petroleum When petroleum is obtained as a heavy crude, it needs to be transported to an upgrading facility for conversion to useful petroleum products.
  • pipeline transport is the most economical means to accomplish this.
  • oil sands When oil sands are used as precursors in the production of synthetic crude oil, they are transported for further processing after extraction and froth treatment through pipelines as a naphtha-diluted bitumen so that they can undergo further upgrading processes, including cracking and coking, amongst other standard refining operations.
  • the heavy oil or oil precursor materials may be transported through pipelines as oil-in-water mixtures or emulsions.
  • Tertiary oil recovery also known as “enhanced” or “improved” oil recovery, makes use of low IFT polymers to produce oil from wells that have stopped producing of their own accord. Injection of a low IFT surfactant into one of these less productive wells can stimulate production from the residual oil left adhered to the surface of porous rocks.
  • the compounds described herein are useful as low IFT surfactants for EOR.
  • Desalting refers to the process of removing salts from oil, making the oil more suitable for further refining.
  • Salts including magnesium chloride, sodium chloride and calcium chloride can be found in crude oil. If allowed to remain in the crude oil during the refinery operation, the salts can dissociate and the chloride ion can ionize to form hydrochloric acid, which, along with various organic acids found in crude oil, contributes to corrosion in refinery equipment.
  • other metal salts e.g., potassium, nickel, vanadium, copper, iron and zinc
  • Crude oil also contains emulsified water, which contains dissolved salts.
  • Desalting crude oil takes advantage of the fact that the salts dissolve in a water phase, which is separable from the oil phase.
  • Crude oil naturally contains water in emulsion, as mentioned above.
  • additional water may be added to the oil (e.g., in an amount between 5-10% by volume of crude) so that the impurities can further dissolve in the water.
  • the water-in-oil emulsion can be broken with the assistance of emulsion-breaking chemicals and/or by exposing the emulsion to an electrical field that polarizes the water phase, so that the water phase bearing the impurities separates from the petroleum phase.
  • Ethoxylated nonylphenols are a class of nonionic surfactants that have been used for desalting crude oil according to these principles.
  • the surfactant compounds disclosed herein can facilitate the demulsification of the water-in-oil emulsion, so that the oil phase separates from the water phase, with the water phase carrying the soluble impurities (i.e., the salts).
  • the hydrophilic portion of the surfactant compound can include one or more ionizable carboxylic acid groups that can be ionized at a basic pH (e.g., >8) to produce an emulsion- sustaining material.
  • acid may be added, removing the charge stabilization and allowing the two phases to segregate from each other.
  • an aqueous surfactant solution comprising an amphiphilic surfactant can be used to emulsify heavy crude oil components that have settled as a sludge at the bottom of the oil containment vessel.
  • a surfactant can be injected into the sludge, thereby forming an oil-in-water emulsion comprising the heavy crude oil components of the sludge, which emulsion can then be removed from the oil containment vessel, thereby desludging it.
  • the sludge to be treated comprises an oil-contaminated sediment that was created by accidental discharge of hydrocarbons onto the ground or a body of water.
  • the sludge to be treated comprises asphaltenes, or it comprises a water-in-oil emulsion.
  • the aqueous surfactant includes a switchable, "smart" surfactant, which can be injected as an aqueous solution into an oil storage vessel to emulsify the heavy oil sludge into the water phase with minimal agitation.
  • a switchable, "smart" surfactant which can be injected as an aqueous solution into an oil storage vessel to emulsify the heavy oil sludge into the water phase with minimal agitation.
  • Establishing water as the continuous phase of the emulsion for the sludge can decrease the sludge viscosity so that it can be pumped out of the storage vessel into an alternate containment system.
  • the sludge-in-water emulsion can be directed to a distinct separation vessel, where the emulsion can then be broken, yielding a phase-separate two-component system comprised of crude oil fractions suitable for further refining and recovered water suitable for reuse in similar or other projects.
  • the surfactant will be injected into the heavy oil sludge (including the rag layer), so that the surfactant can destabilize the heavy oil- water interface to invert the emulsion into the water phase.
  • an amphiphilic, water-soluble polymer can be used that is effective at low concentrations.
  • the resulting water emulsion can be removed from the subject vessel and relocated, for example to a separation vessel. This may take place as a separate step after the first step has been completed. In other embodiments, however, this can take place during the first step. For example, the water emulsion can be siphoned off as it is formed.
  • the water emulsion containing the stabilized oil droplets can be demulsified.
  • a change in the conditions of the water emulsion can change the conformation of the surfactant, so that it breaks into an oil- soluble component and a water-soluble component.
  • the oil-soluble component thus demulsifies the heavy oil droplets, while the water-soluble component remains in the water phase.
  • Surfactant molecules can be designed so that the water-soluble byproduct is non-toxic and environmentally safe.
  • the emulsification and/or separation processes might be carried out at temperatures above ambient, to facilitate flow and emulsification or to cause switching of the surfactant properties.
  • a surfactant in accordance with these formulations and methods can be formulated as a polymer that can emulsify the heavy crudes, but can decompose into one or more oligomers capable of effecting demulsification.
  • Oligomers suitable for demulsifying can include: polyethylene oxide/polypropylene oxide copolymers, cellulose esters, polyethylene/ethylene oxide copolymers, ethoxylated nonylphenols, and the like.
  • a random linear copolymer can act as the emulsifying agent.
  • Such a copolymer can contain regions of ionic charge, such as a quaternary amine or sulfonate, that would be resistant to the high-salt environment in the sludge.
  • the copolymer could further contain nonionic regions having hydrophobicity, such as polycarbonate, polystyrene or styrene maleic anhydride.
  • a demulsifying oligomer (as set forth above) can be covalently attached to the nonionic hydrophobic regions.
  • the sludge would be emulsified using the surfactants to form an oil-in- water emulsion.
  • the emulsion could then be pumped from the subject tank or other vessel to a suitable separation vessel.
  • Heat could be optionally added.
  • the pH could be altered so that the covalent linkage holding the demulsifying moieties in place would be broken. If the covalent bond is a weak one (e.g., an ester bond), it may be altered by adding heat only.
  • alkali may need to be added to the emulsion. With the release of the demulsifying agent from its attachment to the polymer, phase separation of oil and water would occur. Water and oil could then be directed for further processing as separate fluid streams.
  • Disclosed herein are compounds and methods that have utility in cleaning wellbores and the like with a multipurpose water-based formulation that can remove films left behind from the use of synthetic base muds, and at the same time leave the wellbore surface in a hydrophilic state.
  • the disclosed formulations can minimize volumes of cleaning materials utilized for wellbore cleanout, reduce the amount of waste material produced and offer tailored formulations for specific films left by different drilling muds.
  • the hydrophilic regions of the surfactant compounds disclose herein can attract aqueous fluids to wash away or break up the oil and the hydrophobic portion can be designed to have high oil affinity.
  • cuttings are formed that are contaminated with oil. In many situations, they are considered hazardous waste because of their oil content, whether from oil-based drilling fluid or from formation-produced oil. Disposal of these contaminated cuttings is specialized and expensive, because of their hazardous waste status.
  • cuttings generated during the drilling operations can be cleaned using surfactants disclosed herein. Cleaning the cuttings by removing the oil may reduce their hazard burden.
  • the use of switchable surfactants for cleaning cuttings is especially advantageous because the emulsion can be demulsified in a manner that minimizes the contaminated wastewater produced and allows recovery of oil.
  • PLURONIC® L64, L35 and L31 were obtained from BASF Corporation, Florham Park, NJ 07932, USA.
  • JEFF AMINE® ED-900, M-1000, ED-2003, ED-600 were obtained from HUNTSMAN, Austin, TX 78752, USA.
  • Eka SA 210 EKA Chemicals, Inc., Marietta, GA 30062, USA.
  • Example 1 Reaction between alkenylsuccinic anhydride and aliphatic alcohol
  • a reactor was charged with 1 ,3-butanediol (0.64 g, 7.14 mmol) (Aldrich) and Eka SA 210 brand alkylated succinic anhydride (5 g, 14.28 mmol). The mixture was stirred for about 4 hours at 130°C under nitrogen. The product was then analyzed by an AVATAR 360 FT-IR ("IR"). The sample was run in the "Attenuated Total Reflectance mode" placing the sample over a Germanium crystal.
  • a reactor was charged with neopentyl alcohol (3.482 g, 33.4 mmol) (Aldrich) and 2-(l-nonenyl) succinic anhydride (15 g, 66.87 mmol) (Aldrich). The mixture was stirred for about 1.5 hours at 130°C under nitrogen. The product was then analyzed by IR. The sample was run in the "Attenuated Total Reflectance mode" placing the sample over a Germanium crystal. The IR spectra showed the almost complete disappearance of the initial anhydride peaks due to the carbonyl groups (peaks at 1859 and 1778 cm-1), and the appearance of carbonyl peaks at 1735 and 1704 cm-1 due to the formation of ester and acid respectively.
  • the product had very limited solubility in water.
  • a reactor was charged with 2-cyclohexylethanol (5.716 g, 44.58 mmol) (Aldrich) and 2-(l-nonenyl) succinic anhydride (10 g, 44.58 mmol) (Aldrich). The mixture was stirred for about 1.75 hours at 130°C under nitrogen. The product was then analyzed by IR. The sample was run in the "Attenuated Total Reflectance mode" placing the sample over a Germanium crystal. The IR spectra showed the almost complete disappearance of the initial anhydride peaks due to the carbonyl groups (peaks at 1863 and 1781 cm-1), and the appearance of carbonyl peaks at 1734 and 1703 cm-1 due to the formation of ester and acid respectively.
  • the Polyethylene glycol was dried before hand in a vacuum oven at about 80°C for 6 hours. The mixture was stirred for about 6 hours at 130°C under nitrogen. The product was then analyzed by IR. The sample was run in the "Attenuated Total
  • Cloud point (1% aqueous, pH>5) > 90°C.
  • Cloud point (1% aqueous, pH ⁇ 5) 10 - 40°C.
  • a reactor was charged with Poly(ethylene glycol) (Fluka) (molecular weigh 380- 420) (12.82 g, 32 mmol) and Eka SA 210 brand alkylated succinic anhydride (22.58 g, 64 mmol). The mixture was stirred for about 3 hours at 130°C under nitrogen. The product was then analyzed by IR. The sample was run in the "Attenuated Total Reflectance mode" placing the sample over a Germanium crystal. The IR spectra showed the almost complete disappearance of the initial anhydride peaks due to the carbonyl groups (peaks at 1859 and 1778 cm-1), and the appearance of carbonyl peaks at 1735 cm-1 due to the formation of ester.
  • Cloud point (1% aqueous, pH>5) > 90°C.
  • Example 6 Reaction between an ethylene oxide/propylene oxide block copolymer and alkenylsuccinic anhydride
  • the sample was run in the "Attenuated Total Reflectance mode" placing the sample over a
  • the IR spectra showed the almost complete disappearance of the initial anhydride peaks due to the carbonyl groups (peaks at 1859 and 1782 cm-1), and the appearance of carbonyl peaks at 1731 cm-1 due to the formation of ester.
  • Cloud point (1% aqueous, pH>5) > 90°C.
  • a reactor was charged with Poly(ethylene glycol)methyl ether (Mn ⁇ 550) Aldrich (10 g, 18.18 mmol) and 2-(l-nonenyl) succinic anhydride (4.843 g, 18.18 mmol), Aldrich. The mixture was stirred for about 3 hours at 130°C under nitrogen. The product was then analyzed by IR. The sample was run in the "Attenuated Total Reflectance mode" placing the sample over a Germanium crystal. The IR spectra showed the almost complete disappearance of the initial anhydride peaks due to the carbonyl groups (peaks at 1855 and 1781 cm-1), and the appearance of carbonyl peaks at 1731 cm-1 due to the formation of ester.
  • Mn ⁇ 550 Poly(ethylene glycol)methyl ether
  • 2-(l-nonenyl) succinic anhydride 4.843 g, 18.18 mmol
  • Cloud point (1% aqueous, pH>5) > 90°C.
  • Cloud point (1% aqueous, pH ⁇ 5) ⁇ 90°C.
  • Cloud point (1% aqueous, pH>5) > 90°C.
  • Glycidyl hexadecyl ether Aldrich
  • JEFF AMINE® ED-2003 XTJ-502
  • Glycidyl hexadecyl ether Aldrich
  • JEFF AMINE® M-1000 XTJ-506
  • HUNTSMAN Hydrophobic glycidyl ether
  • Cloud point (1% aqueous) 80- 90°C.
  • Cloud point (1% aqueous) 50- 57°C.
  • Cloud point (1% aqueous) 57- 60°C.
  • IFT Interfacial tension
  • the 1% solution of the molecule prepared in accordance with Example 3 is of particular interest because of its low IFT values with all three organic liquids.
  • EOR it is desirable to have such low interfacial tensions with crude oils because EOR surfactant solutions are often used to recover crude oil that is trapped within the capillaries of rock formations.
  • the commercial surfactants Igepal DM-970 and Tergitol 15-S-30 were used to form 1% by weight surfactant solutions to compare with the test surfactant. Deionized water was used as the control. Photographs and phase height measurements were taken at 5, 30, and 60 minutes as well as 24 hours after mixing. Table 2 displays the percentage of the solution occupied by emulsion phase over time for each surfactant (test surfactant and two commercial surfactants). Figure 1 shows the behavior of the emulsion over time, and shows a control sample containing Dl-water (without surfactant). This example demonstrates that the synthesized surfactant of the present invention are capable of stabilizing heavy oil over long periods of time.
  • Surfactant switchability can be induced by the adjustment of mixture pH.
  • Surfactant solutions that exhibit emulsifying characteristics at neutral pH can be deactivated from surface activity when the pH becomes acidic. This will allow for controlled recovery of oil from an otherwise stable emulsion.
  • a test surfactant was compared to the commercial surfactant Tergitol 15-S-7.
  • the surfactant solution was prepared by dissolving the molecule prepared in accordance with Example 3 in deionized water and adjusting the pH to neutral by the addition of 5 M NaOH. Two oil mixtures were prepared for each surfactant solution: initially the two mixtures had neutral pH, but after the vials were agitated and emulsion was formed, a few drops of HC1 10M was added to one of the vials to decrease the pH to ⁇ 3.
  • Figure 2 shows the behavior of the emulsion with and without acid after 5 minutes along with a control sample containing Dl-water (without surfactant) and a 1% solution of a commercial surfactant Tergitol 15-S-7.
  • Example 3 producing a 70:30 oil to water mixture. The mixture was gently stirred until it was observed it achieved a single liquid phase. Previously, the viscosity of the neat heavy oil sample was measured at 3431 cP using a Brookfield DVIII+ Rheometer. The 70:30 mixture exhibited a viscosity of 100.2 cP. Next, 1 mL of 10 M HC1 was added and the mixture was stirred gently, while observing phase separation of the oil and water. The oil sample was decanted from the container and obtained the same viscosity measurement as the untreated heavy oil sample.
  • Example 17 Removal of Crude Oil from Sand Surfaces
  • Example 18 Reaction between an ethylene oxide/propylene oxide block copolymer and phenyl succinic anhydride
  • a reactor was charged with phenyl succinic anhydride (0.564 g, 10.52 mmol) and Pluronic L35 (10 g, 5.26 mmol). The mixture was stirred for about 4 hours at 130°C under nitrogen. The product was then analyzed by IR which showed almost complete disappearance of the anhydride carbonyl peaks (1859 and 1785 cm-1) and the appearance of the ester and acid carbonyl band (1731 cm-1).
  • Cloud point (1% aqueous, pH ⁇ 8) > 100°C.
  • Cloud point (1% aqueous, pH ⁇ 2) 60 - 100°C.
  • Example 19 Reaction between an ethylene oxide/propylene oxide block copolymer and phenyl succinic anhydride
  • a reactor was charged with phenyl succinic anhydride (0.9746 g, 18.2 mmol) and Pluronic L31 (10 g, 9.1 mmol). The mixture was stirred for about 2.5 hours at 130°C under nitrogen. The product was analyzed by IR which showed almost complete disappearance of the anhydride carbonyl peaks (1859 and 1785 cm-1) and the appearance of the ester and acid carbonyl band (1731 cm-1).
  • Cloud point (1% aqueous, pH ⁇ 8) ⁇ 64°C.
  • Example 20 Reaction between an aromatic diacid and a polyetheramine.
  • a reactor was charged with phenyl glycidyl ether (3 g, 20 mmol), Jeffamine M- 1000 brand polyethermonoamine (10 g, 10 mmol) and 25 ml of isopropanol. The mixture was stirred for 5 hours under reflux and under nitrogen. Then the solvent was stripped off under vacuum.
  • a solution prepared in accordance with Example 21 was dissolved into aqueous solution at 1% by weight and the pH was adjusted to 9 by the addition of 1 M sodium hydroxide, to form a surfactant solution.
  • Example 24 Oily sand treatment

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Abstract

La présente invention concerne une classe de nouveaux tensioactifs qui ont une utilité dans la récupération et/ou l'extraction d'huiles.
PCT/US2010/058729 2009-12-10 2010-12-02 Tensioactifs à faible tension interfaciale pour des applications dans le pétrole WO2011071747A1 (fr)

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BR112012014008A BR112012014008A2 (pt) 2009-12-10 2010-12-02 composto tensoativo, método para a preparação de um composto tensoativo e método para extrair óleo de uma mistura de óleos
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CN110709445A (zh) * 2017-04-05 2020-01-17 毕克化学有限公司 作为润湿剂和分散剂的单环氧化物-单胺加合物
CN110709445B (zh) * 2017-04-05 2023-08-08 毕克化学有限公司 作为润湿剂和分散剂的单环氧化物-单胺加合物
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CA2783831C (fr) 2016-03-22
EP2510080A1 (fr) 2012-10-17
US20110309001A1 (en) 2011-12-22
EP2510080A4 (fr) 2013-07-03
AU2010328497A1 (en) 2012-07-05
US8742165B2 (en) 2014-06-03
US9441168B2 (en) 2016-09-13
CA2783831A1 (fr) 2011-06-16
BR112012014008A2 (pt) 2016-04-12
AU2010328497B2 (en) 2014-02-13
US20140346089A1 (en) 2014-11-27
US20170233660A1 (en) 2017-08-17

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