WO2014096813A1 - Hydrocabures - Google Patents

Hydrocabures Download PDF

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Publication number
WO2014096813A1
WO2014096813A1 PCT/GB2013/053331 GB2013053331W WO2014096813A1 WO 2014096813 A1 WO2014096813 A1 WO 2014096813A1 GB 2013053331 W GB2013053331 W GB 2013053331W WO 2014096813 A1 WO2014096813 A1 WO 2014096813A1
Authority
WO
WIPO (PCT)
Prior art keywords
oil
treatment formulation
polymeric material
mole
water
Prior art date
Application number
PCT/GB2013/053331
Other languages
English (en)
Inventor
Ahmed ALJUBORI
Cory JASKA
Sygifredo COBOS
Original Assignee
Oilflow Solutions Holdings Limited
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Oilflow Solutions Holdings Limited filed Critical Oilflow Solutions Holdings Limited
Priority to US14/651,806 priority Critical patent/US20150315479A1/en
Priority to CA2884924A priority patent/CA2884924C/fr
Priority to EP13826576.4A priority patent/EP2935504A1/fr
Publication of WO2014096813A1 publication Critical patent/WO2014096813A1/fr

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Classifications

    • 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
    • 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
    • C09K3/00—Materials not provided for elsewhere
    • C09K3/32—Materials not provided for elsewhere for absorbing liquids to remove pollution, e.g. oil, gasoline, fat
    • 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
    • C09K8/588—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 polymers
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/35—Arrangements for separating materials produced by the well specially adapted for separating solids

Definitions

  • This invention relates to hydrocarbons and particularly, although not exclusively, relates to removal of hydrocarbon-based adherents from a solid substrate.
  • Cleaning agents prepare and clean surfaces by interacting with adherents, altering their properties, and minimizing the tendency of the adherent to adhere to the surface.
  • the chemistry of cleaning agents and surface treatments is highly advanced.
  • Liquid cleaning formulations include degreasers, strippers, passivators, etchants, solutions and additives for cleaning and surface preparation. They are used to remove adherents (grease or oil) from surfaces such as industrial equipment or mechanical components.
  • Formulations for cleaning are often, but not exclusively, water based. They may include the following:
  • Strong alkalis These are extremely caustic solutions used to dissolve greases and certain minerals. Strong alkalis are known to boost the performance of other additives (e.g. chelants and builders described below) as well as to improve the dissolution rates for some minerals and scale deposits. Examples include sodium hydroxide and potassium hydroxide.
  • Medium strength alkalis These are moderately caustic solutions used to remove fats, oils, and some paints and lacquers.
  • Sodium carbonate is an example.
  • Mild alkalis These are slightly basic solutions used for water softening and light cleaning. Sodium bicarbonate and water soluble silicates are examples.
  • Strong acids These are highly corrosive materials used to dissolve hard mineral deposits. Examples include sulphuric, hydrochloric and hydrofluoric acids. Mild acids: These are slightly corrosive materials used to soften water and control mineral deposition. Examples include acetic, citric and gluconic acid.
  • Solvents This category includes a variety of substances used to dissolve grease and oil without the hazards of corrosivity. Solvents for cleaning consist of compounds such as alcohols, chlorinated hydrocarbons, or terpenes. Solvents may replace the water in a formulation or be additives in water based formulations (mutual solvents). Examples include acetone, isopropyl alcohol, d-limonene and 2-butoxyethanol. Solvents may be flammable, toxic and difficult to handle in practice.
  • Surfactants These fall into the general category of detergents that are widely used as household cleaners. There is a multitude of examples including soaps (natural surfactants) and synthetic detergents.
  • Some surfactants are used to emulsify fats, oils, and greases and are effective at lifting organic adherents from surfaces.
  • Other surfactants demulsifiers
  • surfactants are designed to release solid materials from the body of slurries, composed of highly viscous emulsions, within which the solid materials may be entrained.
  • surfactants can be highly effective.
  • many surfactants are associated with environmental disadvantages.
  • surfactants when used to clean oil from surfaces, surfactants can bind the oil so strongly into emulsions that the oil cannot be recovered and converted into gasoline or even disposed of safely and in a cost effective manner.
  • Dispersants This category of additives shows behaviour that is closely related to that of surfactants. Their activity may be milder than that of surfactants or detergents. They are designed to prevent adherents, once cleaned from surfaces, from re-agglomerating rapidly. This slow agglomeration provides benefits such as stability or enhanced biodegradation due to increases in the surface area of contaminant droplets. Examples include polyelectrolytes, polysaccharide gums or lignosulphonates.
  • Chelants, Sequestrants and Builders are organic substances, which are soluble or miscible with water, that are added to formulations to minimize harmful characteristics of hardness ions such as cationic forms of calcium, magnesium, iron and manganese. Such ions interfere with the cleaning ability of primary active components (detergents and surfactants), effectively consuming them and making them unavailable to act on the surfaces to be cleaned. Chelants, sequestrants and builders 'bind up' the harmful ions converting them into harmless configurations where they cannot consume the primary active components.
  • substances in this category include polydentate ligands such as ethylene diamine tetraacetic acid, polyphosphonates, gluconates, polyols, glucoheptonates, thioglycollic acid, water soluble silicates and certain carbonates.
  • polydentate ligands such as ethylene diamine tetraacetic acid, polyphosphonates, gluconates, polyols, glucoheptonates, thioglycollic acid, water soluble silicates and certain carbonates.
  • Preservatives These are incorporated in formulations to protect soaps and detergents against the natural effects of aging such as decay, discoloration, oxidation and bacterial degradation. Examples of preservatives include butylated hydroxytoluene, methyl or propyl paraben and water soluble compounds of tin.
  • This cleaning process leads to approximately 75% of the bitumen being extracted from the oil sand.
  • the extracted bitumen froth at this stage, is still contaminated with water and residual sand and its composition is approximately 60% petroleum, 20% solids and 30% water.
  • the caustic materials, used in the process have high alkalinity and may chemically modify the solids, contributing to the formation of fine clay particles or militating against the further removal of such solid material.
  • the process leaves a significant amount of oil in a watery phase (referred to as the "middling") below the froth and a bottom layer comprising sand and silt may also contain some oil.
  • Said treatment formulation may have a surface tension (in the absence of any oil) at 25 °C, preferably in the range 35 to 66 mN/m, more preferably in the range 40 to 65 mN/m.
  • Said treatment formulation suitably comprises water and said polymeric material, wherein suitably said polymeric material affects the IFT of the treatment formulation in relation to said adherent and/or modifies the water so it has the IFT as described herein.
  • Said treatment formulation is suitably aqueous. It suitably comprises at least 80 wt%, preferably at least 90 wt%, more preferably at least 95 wt%, especially at least 98 wt% water. It may include 99.9 wt% or less of water.
  • Said treatment formulation suitably includes at least 0.1 wt%, preferably at least 0.2 wt%, more preferably at least 0.4 wt% of said polymeric material. It may include less than 2 wt%, preferably less than 1 % , more preferably less than 0.5 wt%.
  • Said treatment formulation suitably includes 96 to 99.9 wt% of water, 0.1 to 1 wt% of said polymeric material and 0 to 3 wt% of other additives, such as biocides or corrosion inhibitors.
  • the amount of other additives may be less than 2.5 wt%, suitably less than 2.0 wt%, preferably less than 1 wt%.
  • said treatment formulation includes 98 to 99.9 wt% of water, 0.1 to 0.5 wt% of said polymeric material and 0 to 2wt% of other additives. Water for use in the treatment formulation may be derived from any convenient source.
  • Said polymeric materials is preferably non-ionic.
  • Said polymeric material may have a weight average molecular weight (Mw) of less than 200,000, suitably less than 150,000, preferably less than 100,000, more preferably less than 50,000.
  • the Mw may be at least 5,000, preferably at least 1 0,000.
  • the Mw may be in the range 5,000 to 25,000, more preferably in the range 10,000 to 25,000.
  • the preferred polymeric material for said treatment formulation may have a higher molecular weight compared to when higher API oils are being treated.
  • the weight average molecular weight may be greater than 50,000, or greater than 75,000 or greater than 100,000.
  • the molecular weight may be less than 300,000 or less than 250,000.
  • the concentration of the polymeric material may be greater than when high API oils are being treated.
  • the treatment formulation may include at least 0.5 wt%, for example 0.5 to 3 wt% or 1 to 2 wt% of said polymeric material.
  • Weight average molecular weight may be measured by light scattering, small angle neutron scattering x-ray scattering or sedimentation velocity.
  • the viscosity of the specified aqueous solution of the polymeric material may be assessed by Japanese Standards Association (JSA) JIS K6726 using a Type B viscometer. Alternatively, viscosity may be measured using other standard methods. For example, any laboratory rotational viscometer may be used such as an Anton Paar MCR300.
  • the viscosity of a 4wt% aqueous solution of the polymeric material at 20 °C may be at least 2.0cP, preferably at least 2.5cP.
  • the viscosity may be less than 6cP, preferably less than 5cP, more preferably less than 4cP.
  • the viscosity is preferably in the range 2 to 4cP.
  • the aforementioned viscosity suitably refers to a situation for oils other than bitumen being treated.
  • the viscosity (and the molecular weight as discussed above) of the polymeric material used in the treatment formulation may be higher.
  • Said polymeric material preferably includes a saturated, preferably aliphatic, hydrocarbon backbone.
  • Said polymeric material may include more than two different repeat units. However, preferably it includes no more than two different types of repeat units.
  • the mole% of vinylalcohol repeat units divided by the mole% of vinylacetate repeat units may be in the range 1 .5 to 19, preferably in the range 2 to 15, more preferably in the range 4 to 12.
  • Said polymeric material suitably comprises at least 50 mole%, preferably at least 60 mole%, more preferably at least 70 mole%, especially at least 80 mole% of vinylalcohol repeat units. It may comprise less than 99 mole%, suitably less than 95 mole %, preferably less than 91 mole% of vinylalcohol repeat units. Said polymeric material suitably comprises 60 to 99 mole%, preferably 80 to 95 mole%, more preferably 85 to 95 mole%, especially 80 to 91 mole% of vinylalcohol repeat units.
  • Said polymeric material is preferably not cross-linked.
  • the sum of the mole% of vinylalcohol and vinylacetate repeat units in said polymeric material is at least 80 mole%, preferably at least 90 mole%, more preferably at least 95 mole%, especially at least 99 mole%.
  • Said polymeric material preferably comprises 70-95 mole%, more preferably 80 to 95 mole%, especially 85 to 91 mole% hydrolysed polyvinylalcohol.
  • Said treatment formulation may be at a temperature of at least ambient temperature immediately prior to contact with said solid substrate.
  • Said treatment formulation suitably has a viscosity at 25 S C and 1 00s "1 of greater than
  • said solid substrate and/or said treatment formulation may be agitated after contact so as to mix the treatment formulation and solid substrate.
  • the method of the first aspect preferably includes separating treatment formulation which includes adherent (e.g. oil) from solid substrate with which it was previously associated .
  • the treatment formulation and adherent suitably form a dispersion which comprises the adherent dispersed in water of the treatment formulation .
  • This dispersion may be separated from the solid substrate by any suitable means.
  • the method of the first aspect preferably includes a step of selecting said dispersion and treating it to produce a first part and a second part.
  • Said first part preferably comprises water and said first polymeric material, wherein the concentration of adherent in said first part is less than the concentration in said dispersion .
  • the ratio of the concentration in said dispersion divided by the concentration in said first part may be at least 2, 3 or 4.
  • Said second part preferably comprises said adherent, wherein the concentration of water in said second part is less than the concentration of water in the dispersion.
  • the treatment to produce said first and second parts suitably comprises the dehydration of said dispersion to produce a first part which includes less adherent than in said dispersion and a second part which includes more adherent than in said dispersion.
  • the method of the first aspect may be used to enhance production- oil recovery.
  • the method may comprise extracting a mass of solid substrate containing an adherent which is a crude oil from the ground.
  • the mass is preferably naturally occurring in the ground. It preferably includes particulates in combination with oil both of which suitably occur together naturally as a mass in the ground.
  • the particulates preferably occur naturally as particulates in the ground.
  • the particulates are indigenous in the ground. They are suitably different to any particulates used or formed during an intervention (e.g. drilling) by an operator.
  • the mass is preferably derived from (e.g.
  • a region of ground which is at least 5m, 10m, 15m or 50m from an imaginary vertical line (or a real vertical line where the mass is removed from the ground via a wellbore) which defines a position wherein the mass is removed from the ground.
  • Said mass suitably includes at least 3wt%, preferably at least 5wt%, more preferably at least 8wt% of crude oil. It may include less than 40wt% of crude oil. It may include at least 3wt% of water. Said mass preferably includes at least 5wt% of naturally-occurring particulate material, for example indigenous particulates as described. Particulates as described may comprise gravel, sand, silt and/or clays. Said mass preferably includes at least some sand.
  • the mass is suitably extracted as described and is contacted with treatment formulation at the surface to remove oil from the solids (e.g. particulates) included in the mass.
  • a first example of the first embodiment may comprise removing bitumen from oil sands, obtained for example by mining.
  • oil sands may comprise a mass which includes 75 to 85wt% of inorganic materials (e.g. sand, clay and/or minerals); it may include 3 to 6wt% water; and it may include 10 to 20wt% of bitumen.
  • the bitumen by definition has an API gravity of less than 10°
  • the oil sands may be contacted with said treatment formulation, and suitably agitated.
  • a slurry is suitably formed which may be allowed to separate, optionally assisted by gravity and agitation.
  • the separation preferably includes forming a bitumen froth, which may optionally be enhanced by bubbling a gas through the slurry.
  • Use of the treatment formulation enhances separation of the bitumen from other components of the slurry.
  • a second example of the first embodiment may comprise a CHOPS process.
  • the mass extracted from the ground suitably comprises oil and sand; it is preferably extracted via a wellbore, suitably under the motive of a surface pump, for example a progressing cavity pump or mechanical beam pump.
  • the oil is suitably mobile enough to flow. It may have a viscosity in the range 10,000cP to 1 50,000cP at 25 °C and, more commonly, in the range 20,000cP to 70,000cP.
  • the mass may include 5 to 40wt% sand, 1 to 90wt% water (more commonly 5 to 50wt% water) and 5 to 94wt% oil, (more commonly 50 to 90wt%).
  • the treatment formulation may be associated with the mass in the separation vessel and may facilitate removal and/or isolation of the oil from the sand.
  • the method of the first aspect may be used to remove adherent, for example oil, from a solid substrate primarily to decontaminate the solid substrate, rather than primarily recover oil for subsequent use. Decontamination of the solid substrate may facilitate disposal of the solid substrate in accordance with legislation or other appropriate commercial practices.
  • the method may include disposing of the solid substrate after the level of oil contained in it has been reduced in the method.
  • the liquid removed from the solid substrate may be treated to facilitate separation of an oil-rich part and a water-rich part.
  • a first example of the second embodiment may comprise treating waste sand from a CHOPS well with said treatment formulation.
  • oil-containing sludge in a receptacle for example a tank may be contacted with said treatment formulation to facilitate mobilisation of the sludge and extraction and/or isolation of an oil-rich part therefrom.
  • the method may be used to clean a conduit, for example a pipe or wellbore, and/or remove oil therefrom.
  • BEU Batch Extraction Unit
  • the light oil may be selected from vegetable oil, diesel oil, kerosene, canola oil and olive oil.
  • the aforementioned components of the treatment formulation are suitably blended so that the oil is dispersed in the aqueous phase, wherein the aqueous phase suitably contains said polymeric material.
  • the formulation may be used to remove heavy oil (e.g. oil having an API lower than that of said light oil). Said heavy oil may have an API of less than 30°, suitably less than 25° or less than 20°.
  • the light oil in the formulation is believed to act as a cleaning agent in use. It is believed the formulation works because the dispersed light oil droplets have a high surface area, through which the heavy oil adherent is consumed, perhaps by simple dilution. In some situations, it may be desirable to stabilise the formulations, using surfactants or fine solids; however, if aggressive shearing is used in preparation of the formulations, the formulations may, in any event, be relatively stable.
  • the formulation described may be used to remove heavy oil as described from a solid substrate.
  • sludge for example a sand-based "pit sludge" (e.g. containing 1 0 to 20 wt% of water, 35 to 55 wt% hydrocarbons and 25 to 55 wt% solids) may be treated with the formulation, for example mixed with it. After treatment, the solids are found to be relatively clean. There may also be an associated water phase and a separate oil phase which includes oil from the sludge dissolved in the light oil.
  • a method of recovering oil from a subterranean formation which comprises:
  • the process was first repeated using progressively decreasing proportions of the polymer in the treatment fluid, and again using oil II.
  • Example 3 Dispersion formation with multiple oils
  • Table 1 shows measured values of apparent viscosity at selected wall shear rates (flow curve), along with the corresponding shear rate independent viscosities for the three oils.
  • Table 1 indicates that the apparent viscosities of the dispersions reduce to a single flow curve i.e. the dispersion characteristics are standardised regardless of the original oil viscosity.
  • Table 2 shows the rheological properties of dispersions made with different brines. Table 2: Apparent Viscosities at Selected Wall Shear Rates (Flow Curves) in Different
  • Oil X having shear rate independent viscosity at 20°C of 10,000cP c Oil XI having shear rate independent viscosity at 20°C of 725cP d Tap water
  • Figure 3 shows plots of water retained in the oil vs time for both oil tested. In both cases, separation is rapid, with over 90% of the treatment fluid being released within 24 hours. By comparison, with many surfactants, a substantial proportion of the oil may have been entrained practically irreversibly in the dispersion.
  • IFT as described herein may be measured as described in Example 6.
  • the method is generally in accordance with Shi-Yow Lin, Li-Jen Chen, Jia-Wen Xyu and Wei-Jiunn Wangi, Langmuir 1996, 1 1, 4159-41 66 41 59. It was undertaken at 25 °C. However, since oils are too viscous to pass through the needle, the oil was diluted with toluene prior to being tested at an oil:toluene ratio of 75:25.
  • a Kruss DSA1000 Surface Tensiometer was used to measure IFT between two liquids at ambient temperature with a J-Needle. In the method, a fluid drop, of a certain shape, is created hanging from an upturned needle while suspended in an optical cell containing another fluid and mathematical equations are used to calculate the Interfacial Tension between those two fluids. The procedure used was as follows:
  • the treatment formulations described have an excellent balance of detergency, dispersion and emulsion breaking properties. Such a balance in properties may be highly beneficial in the processes described herein.
  • Hydrocarbons may be sludges taken from storage tanks or produced by refinery processes.
  • a solid substrate may be siliceous materials, sand, aluminosilicates, clays or cuttings from the oilwell drilling process. They may be metallic surfaces of pipes, storage tanks, rail cars or other receptacles. Alternatively, the solid substrate may exist as discrete particles having mean number average particle sizes in the range 5 microns to 500microns as determined by laser light scattering methods.
  • a treatment formulation as described may be used in removing bitumen from oil sands.
  • a pre-soak with a treatment formulation comprising polyvinylalcohol I, immediately prior to mechanical separation, may enable a greater quantity of oil to be recovered and a less restrictive disposal classification to be achieved.
  • a treatment formulation as described may be used in sludge mobilisation.
  • hydrocarbon containing materials may be stored in tanks and pits for some time.
  • the hydrocarbon containing materials may be transported in metal tanks on rail cars or in oil tankers. The continued use of such vessels leads to the build up of sludge due to the settling of solids suspended in the oil.
  • These sludges are difficult to handle and often need to be manually removed. This involves working in confined spaces; an activity which carries safety risks from accidents or the inhalation of toxic gases.
  • a treatment formulation comprising polyvinylalcohol may be used to mobilise sludge and facilitate extraction with much less manual intervention.

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  • Chemical & Material Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Organic Chemistry (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Materials Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Fluid Mechanics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Public Health (AREA)
  • Health & Medical Sciences (AREA)
  • Wood Science & Technology (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Detergent Compositions (AREA)

Abstract

L'invention concerne un procédé permettant d'éliminer des matières adhérentes à base d'hydrocarbures, par exemple le bitume, d'un substrat solide, par exemple les sables bitumineux, ledit procédé consistant à mettre en contact le substrat solide, qui comprend la matière adhérente à base d'hydrocarbures, avec une préparation de traitement renfermant une matière polymère comportant des unités redondantes d'alcool vinylique et d'acétate vinylique. La matière polymère peut être un alcool polyvinylique hydrolysé de 70 à 95 % en mole.
PCT/GB2013/053331 2012-12-21 2013-12-18 Hydrocabures WO2014096813A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
US14/651,806 US20150315479A1 (en) 2012-12-21 2013-12-18 Hydrocarbons
CA2884924A CA2884924C (fr) 2012-12-21 2013-12-18 Adhesifs a base d'hydrocarbure retires d'un substrat solide
EP13826576.4A EP2935504A1 (fr) 2012-12-21 2013-12-18 Hydrocabures

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GBGB1223171.8A GB201223171D0 (en) 2012-12-21 2012-12-21 Hydrocarbons
GB1223171.8 2012-12-21

Publications (1)

Publication Number Publication Date
WO2014096813A1 true WO2014096813A1 (fr) 2014-06-26

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PCT/GB2013/053331 WO2014096813A1 (fr) 2012-12-21 2013-12-18 Hydrocabures

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US (1) US20150315479A1 (fr)
EP (1) EP2935504A1 (fr)
CA (1) CA2884924C (fr)
GB (1) GB201223171D0 (fr)
WO (1) WO2014096813A1 (fr)

Cited By (1)

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Publication number Priority date Publication date Assignee Title
WO2017047616A1 (fr) * 2015-09-15 2017-03-23 株式会社クラレ Stabilisant de dispersion pour huile brute

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Publication number Priority date Publication date Assignee Title
WO2007092631A2 (fr) * 2006-02-09 2007-08-16 Gerard Caneba Tensioactifs multipolymères multifonctionnels pour la récupération du pétrole et du bitume et autres applications
US20100294497A1 (en) * 2006-11-01 2010-11-25 Michael John Crabtree Recovery of oil
US20120222867A1 (en) * 2009-10-15 2012-09-06 Oilflow Solutions Holdings Limited Hydrocarbons
US20120267113A1 (en) * 2009-08-26 2012-10-25 Oilflow Solutions Holdings Limited Treatment of oil

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Publication number Priority date Publication date Assignee Title
GB0711635D0 (en) * 2007-06-15 2007-07-25 Proflux Systems Llp Hydrocarbons
PE20100438A1 (es) * 2008-06-05 2010-07-14 Georgia Pacific Chemicals Llc Composicion de suspension acuosa con particulas de materiales valiosos e impurezas
WO2011153070A1 (fr) * 2010-06-02 2011-12-08 Biolargo Life Technologies, Inc. Modération d'environnements de déchets d'extraction de pétrole

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2007092631A2 (fr) * 2006-02-09 2007-08-16 Gerard Caneba Tensioactifs multipolymères multifonctionnels pour la récupération du pétrole et du bitume et autres applications
US20100294497A1 (en) * 2006-11-01 2010-11-25 Michael John Crabtree Recovery of oil
US20120267113A1 (en) * 2009-08-26 2012-10-25 Oilflow Solutions Holdings Limited Treatment of oil
US20120222867A1 (en) * 2009-10-15 2012-09-06 Oilflow Solutions Holdings Limited Hydrocarbons

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
SHI-YOW LIN; LI-JEN CHEN; JIA-WEN XYU; WEI-JIUNN WANGI, LANGMUIR, vol. 11, 1996, pages 4159 - 4166 4159

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2017047616A1 (fr) * 2015-09-15 2017-03-23 株式会社クラレ Stabilisant de dispersion pour huile brute
US10919012B2 (en) 2015-09-15 2021-02-16 Kuraray Co., Ltd. Crude oil dispersion stabilizer

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Publication number Publication date
CA2884924A1 (fr) 2014-06-26
CA2884924C (fr) 2020-08-25
GB201223171D0 (en) 2013-02-06
US20150315479A1 (en) 2015-11-05
EP2935504A1 (fr) 2015-10-28

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