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
  • C10G7/00—Distillation of hydrocarbon oils
  • C10G7/04—Dewatering
• • 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
  • C10G2300/10—Feedstock materials
  • C10G2300/1011—Biomass
  • C10G2300/1014—Biomass of vegetal origin
• • 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
  • C10G2300/202—Heteroatoms content, i.e. S, N, O, P
• • 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
  • C10G2300/202—Heteroatoms content, i.e. S, N, O, P
  • C10G2300/203—Naphthenic acids, TAN
• • 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
• • 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
  • C10G2300/30—Physical properties of feedstocks or products
  • C10G2300/301—Boiling range
• • 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
  • C10G2300/30—Physical properties of feedstocks or products
  • C10G2300/302—Viscosity
• • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
  • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
  • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
  • Y02P30/00—Technologies relating to oil refining and petrochemical industry
  • Y02P30/20—Technologies relating to oil refining and petrochemical industry using bio-feedstock

Definitions

• the invention relates to a method for upgrading of a pyrolysis oil.
• the method also relates to a fuel product based on the upgraded pyrolysis oil and a hydrocarbon product fraction based on the upgraded pyrolysis oil.
• lignocellulosic material may generally comprise
• hydrocarbons oxygenated compounds, such as sugars, organic acids and phenolics, insoluble lignin and water.
• oxygenated compounds such as sugars, organic acids and phenolics, insoluble lignin and water.
• a portion of the water present in the pyrolysis oil may originate from the starting biomass and another portion may be a pyrolysis product.
• the water content may amount to 25 - 30 %wt, or even more.
• the presence of water and oxygenated compounds in the pyrolysis oil is disadvantageous for the caloric value of the pyrolysis oil.
• oxygenated compounds may be reduced in a hydrodeoxygenation step.
• Water may be removed by evaporation.
• the pyrolysis oil may be upgraded to obtain liquid and/or gaseous fuels. The upgrading process is preferably carried out in standard equipment of an oil refinery.
• the evaporation of water from a mixture of the pyrolysis oil and the high boiling hydrocarbon does not lead to formation of a highly viscous, tar like material, but instead a liquid mixture can be obtained.
• the formation of insoluble material has been found to be negligibly low.
• the residual liquid obtained suitably comprises less organic acids and other light oxygenates, compared to the starting pyrolysis oil, when the evaporation is carried out in the presence of the high boiling
• An additional advantage of removing of organic acids may be that the oil becomes less acidic and less corrosive.
• the present finding advantageously provides new opportunities of using pyrolysis oil as a fuel oil component for marine and/or stationary applications, and as a
• feedstock for hydrocarbon conversion processes for the production of liquid petroleum gas, gasoline, kerosene, diesel, and fuel oils.
• the present invention also provides a method for upgrading of a pyrolysis oil, which method comprises evaporating water from a mixture comprising the pyrolysis oil and a hydrocarbon having an atmospheric boiling point of at least 130 °C .
• the present invention also provides a fuel product which is obtainable by employing the method of this
• the method additionally comprises the step of producing the mixture by mixing the pyrolysis oil and the hydrocarbon .
• the method of the invention comprises
• the present invention also provides a fuel product obtainable by combining in a mixture a pyrolysis oil and a hydrocarbon having an atmospheric boiling point of at least 130 °C and evaporating water from the mixture to a water content of the mixture of at most 5 %wt .
• the present invention also provides a fuel product obtainable by combining in a mixture a pyrolysis oil and a hydrocarbon having an atmospheric boiling point of at least 130 °C and evaporating water from the mixture, which fuel product has a solids content of at most 10 %wt, relative to the weight of the pyrolysis oil, wherein solids content is as measured by using the Hot filtration test according to ASTM D4870, modified in that the prescribed rinsing of the filter employed in the Hot filtration test is followed by rinsing with ethanol.
• the present invention also provides a fuel product obtainable by combining in a mixture a pyrolysis oil and a hydrocarbon having an atmospheric boiling point of at least 130°C and evaporating water from the mixture, which fuel product has a kinematic viscosity measured at 50°C which kinematic viscosity is constant within 15 % during storage of the fuel product at 50 °C for a period of 14 days, wherein kinematic viscosity is as measured according to ASTM D445.
• the present invention also provides a fuel product
• A represents the Total acid number of the pyrolysis oil
• B represents the weight fraction of the pyrolysis oil in the mixture comprising the pyrolysis oil and the high boiling hydrocarbon, wherein Total acid number is as measured by using ASTM D664.
• the present invention also provides a hydrocarbon
• the pyrolysis oil for use in this invention is obtained or derived from biomass comprising lignocellulosic material.
• a lignocellulosic material is herein preferably understood a material containing cellulose, lignin and optionally
• the biomass may generally be of plant origin.
• the biomass may comprise agriculture waste, forest residue, wood chips, straw, chaff, grain, grasses, corn, corn husks, bagasse, weeds, aquatic plants, hay and any
• cellulose containing material or material of biological origin also including municipal waste, or waste paper.
• the biomass comprises forest residues or
• Pyrolysis of the biomass provides the pyrolysis oil for use in this invention.
• pyrolysis is herein preferably understood a process in which the biomass is decomposed at a high temperature, preferably in the absence of oxygen, into gaseous, liquid and solid products.
• the condensable fraction of pyrolysis vapors forms the pyrolysis oil.
• the high temperature is preferably in the range of from 400 °C to 800 °C, more preferably in the range of from 450 °C to
• pretreatment of the biomass, or catalysts may be added to the pyrolysis mixture, cf. for example, H Wang cs . , "Effect of acid, alkali, and steam explosion pretreatment on
• a flash pyrolysis process the biomass is rapidly heated in the absence of oxygen to a temperature in the range of from 400 °C to 600 °C and kept at that temperature for a short period of time.
• the water content of the pyrolysis oil has been reported to amount to up to 40 %wt .
• Such flash pyrolysis processes are known, for example from
• the pyrolysis oil for use in this invention preferably comprises hydrocarbons, oxygenated compounds and water.
• the oxygenated compounds may comprise aldehydes, organic acids, carbohydrates, phenols, furfurals, alcohols and ketones.
• the carbon content of the pyrolysis oil may be in the range of from 35 %wt to 75 %wt, more preferably in the range of from 40 %wt to 55 %wt, for example in the range of from 45 %wt to 50 %wt .
• the hydrogen content may be in the range of from 4 %wt to 7 %wt, more preferably in the range of from 5 %wt to 6 %wt .
• the oxygen content may be in the range of from 15 %wt to 55 %wt, more preferably in the range of from 40 %wt to 50 %wt, for example in the range of from 45 %wt to 50 %wt .
• the nitrogen content may be in the range of from 0.05 %wt to 1 %wt, more preferably in the range of from 0.1 %wt to 0.5 %wt .
• the sulfur content may be in the range of from 0.005 %wt to 0.05 %wt, more preferably in the range of from 0.01 %wt to 0.02 %wt .
• the water content may be at least 1 %wt or at least 2 ⁇ 6 , more
• the Total acid number of the pyrolysis oil may be at most 250 mg KOH/g, more preferably in the range of from 5 mg KOH/g to 200 mg KOH/g, for example in the range of from 10 mg KOH/g to
• carbon content, hydrogen content and nitrogen content are as measured by ASTM D5291, and sulfur content is as measured by ASTM D2622.
• Oxygen content is calculated by difference, such that the sum of carbon content, hydrogen content, oxygen content, nitrogen content and sulfur content is 100 %wt .
• Water content is as measured by ASTM E203.
• Total acid number is as measured by using ASTM D664.
• water is evaporated from the pyrolysis oil, with the pyrolysis oil being present in admixture with a hydrocarbon having an atmospheric boiling point of at least 130 °C .
• a hydrocarbon is herein preferably understood a compound containing both hydrogen atoms and carbon atoms, more preferably the hydrocarbon may be a compound consisting of hydrogen atoms and carbon atoms.
• the hydrocarbon having an atmospheric boiling point of at least 130 °C may be referred to hereinafter by using the term "high boiling hydrocarbon".
• the high boiling hydrocarbon is present in addition to any hydrocarbons that may already be present in the pyrolysis oil itself.
• the high boiling hydrocarbon is a petroleum derived hydrocarbon.
• a petroleum derived hydrocarbon is herein preferably understood a hydrocarbon that is derived from a so-called petroleum crude oil.
• the high boiling hydrocarbon may be a single
• a high boiling hydrocarbon mixture is employed.
• Such a high boiling hydrocarbon mixture suitably contains two or more high boiling hydrocarbons.
• such a high boiling hydrocarbon mixture may comprise a refinery stream, such as a distillation fraction of a mineral crude.
• the high boiling hydrocarbon mixture comprises atmospheric gas oil, vacuum gas oil, flashed distillate, coker gas oil, residual fuel oil, atmospheric residue (also referred to as long residue) , or vacuum residue (also referred to as short residue) , or blends of such refinery streams.
• the high boiling hydrocarbon comprises a refinery stream, it may comprise to some extent
• hydrocarbons having hetero atoms, such as sulfur and/or nitrogen, incorporated in their molecular structure hydrocarbons having hetero atoms, such as sulfur and/or nitrogen, incorporated in their molecular structure.
• the atmospheric boiling point of the high boiling hydrocarbon is at least 130 °C .
• the boiling point of the hydrocarbon is at least 150 °C, more preferably at least 180 °C .
• the initial atmospheric boiling point of the high boiling hydrocarbon mixture may be at least 130 °C, and, preferably, the initial atmospheric boiling point of the high boiling hydrocarbon mixture may be at least 150 °C, more preferably at least 180 °C .
• the atmospheric boiling point range of the high boiling hydrocarbon mixture may be from 220 °C to 800 °C, more preferably from 300 °C to 700 °C.
• the hydrogen to carbon weight ratio (H/C ratio) of the high boiling hydrocarbon mixture may be at most 0.15 w/w, more preferably in the range of from 0.1 to 0.14 w/w, even more preferably in the range of from 0.11 to 0.13 w/w.
• the asphaltenes content of the high boiling hydrocarbon mixture may be equal to or more than 0.2 %wt (percent by weight), more preferably equal to or more than 0.7 %wt, still more preferably equal to or more than 2.0 %wt, even more preferably in the range of from 0.8 to 30 %wt, still even more preferably in the range of from 2.0 %wt to 30 %wt, relative to the weight of the high boiling hydrocarbon mixture.
• the asphaltenes content is in the range of from 0.9 to 15 %wt or in the range of from 2.0 to 15 %wt relative to the weight of the high boiling hydrocarbon mixture.
• boiling point is the atmospheric boiling point, unless indicated otherwise, with the
• initial boiling point and boiling point range of the high boiling hydrocarbon mixtures are as determined by ASTM D2887.
• pressure is absolute pressure.
• H/C ratio is as
• asphaltenes content or C7-asphaltenes content is as determined by IP143, using n-heptane as a solvent.
• the mixture of the pyrolysis oil and the high boiling hydrocarbon can be produced in any manner known to the skilled person in the art.
• the pyrolysis oil may be added to the high boiling hydrocarbon, or the high boiling
• hydrocarbon may be added to pyrolysis oil, or streams of the pyrolysis oil and the high boiling hydrocarbon may be brought together.
• the combination of the pyrolysis oil and the high boiling hydrocarbon may be mixed.
• hydrocarbon may be combined in a weight ratio of pyrolysis oil to high boiling hydrocarbon (grams pyrolysis oil/grams high boiling hydrocarbon) of at least 0.5/99.5, more
• the pyrolysis oil and the high boiling hydrocarbon may be combined in a weight ratio of pyrolysis oil to high boiling hydrocarbon (grams
• hydrocarbon may also be a high boiling hydrocarbon mixture and in such case the same weight ratio's are preferred.
• the amount of pyrolysis oil in a mixture comprising the pyrolysis oil and a high boiling hydrocarbon mixture varies depending on the asphaltene content of the high boiling hydrocarbon mixture. This may allow for an optimal stability of the mixture comprising the pyrolysis oil and the high boiling hydrocarbons.
• the weight ratio of pyrolysis oil to high boiling hydrocarbon mixture (grams pyrolysis oil/grams high boiling
• hydrocarbons is preferably equal to or less than 10/90, more preferably in the range from equal to or more than 0.5/99.5 to equal to or less than 10/90.
• a high boiling hydrocarbon mixture comprising in the range from more than 0.2 wt% to equal to or less than 0.5wt% of
• the weight ratio of pyrolysis oil to high boiling hydrocarbon mixture is preferably equal to or less than 15/85, more preferably in the range from equal to or more than 0.5/99.5 to equal to or less than 15/85.
• the weight ratio of pyrolysis oil to high boiling hydrocarbon mixture is preferably equal to or less than 20/80, more preferably in the range from equal to or more than 0.5/99.5 to equal to or less than 20/80.
• the weight ratio of pyrolysis oil to high boiling hydrocarbon mixture is preferably equal to or less than 30/70, more preferably in the range from equal to or more than 0.5/99.5 to equal to or less than 30/70.
• the weight ratio of pyrolysis oil to high boiling hydrocarbon mixture is preferably equal to or less than 60/40, more preferably in the range from equal to or more than 0.5/99.5 to equal to or less than 60/40.
• the pyrolysis oil and the high boiling hydrocarbon can be mixed in any manner known by the skilled in the art to be suitably for mixing, for example by means of a mixer or via one or more baffles.
• Evaporating water may be carried out in a conventional distillation apparatus.
• a flash distillation apparatus or a distillation apparatus having a separation column may be selected.
• the separation column may preferably be selected and operated such that it comprises at most fifty
• the separation column may preferably be selected and operated such that it comprises at most ten (inclusive) or at most five (inclusive) theoretical trays.
• Evaporating water may be carried out in a continuous operation or as a batch operation.
• the bottom temperature is selected such that the bottom fraction is sufficiently low in viscosity, and the rate of evaporation of water is sufficiently high at the prevailing pressure and remains sufficiently high at
• a bottom temperature in the range of from
• 50 °C to 200 °C may be selected, more suitable in the range of from 80 °C to 150 °C .
• the pressure may suitably be selected in the range of from 0.01 kPa to 120 kPa, more suitably in the range of from 0.1 kPa to 60 kPa, preferably in the range of from 0.2 kPa to 10 kPa (kiloPascal) .
• atmospheric boiling point range the skilled person will appreciate that the atmospheric boiling point or atmospheric boiling point range are specified such that a distillation apparatus can be operated at a pressure other than
• Evaporation of water may preferably be effected to the extent that a bottom fraction is obtained having a water content of at most 5 %wt, more preferably at most 2 %wt, preferably at most 1 %wt, relative to the weight of the bottom fraction.
• the water content of the bottom fraction obtained may be at least 0.001 %wt, or at least 0.01 %wt, relative to the weight of the bottom fraction.
• the bottom fraction so obtained may be referred to by the term "de- watered pyrolysis oil mixture".
• the solids content of the de-watered pyrolysis oil mixture may be at most 1 %wt, more preferably at most 0.5 %wt, relative to the weight of the de-watered pyrolysis oil mixture.
• the solids content of the de-watered pyrolysis oil mixture may be at least 0.005 %wt, more preferably at least 0.01 %wt, relative to the weight of the de-watered pyrolysis oil mixture.
• the solids content of the de- watered pyrolysis oil mixture may be at most 10 %wt, more preferably at most 5 %wt, relative to the weight of the pyrolysis oil present in the mixture of the pyrolysis oil and the high boiling hydrocarbon, before evaporating water.
• the solids content of the de-watered pyrolysis oil mixture may be at least 0.05 %wt, more preferably at least 0.1 %wt, relative to the weight of the pyrolysis oil present in the mixture of the pyrolysis oil and the high boiling hydrocarbon, before evaporating water.
• solids content is as measured by using the Hot filtration test according to ASTM D4870, modified in that the prescribed rinsing of the filter employed in the Hot filtration test is followed by rinsing with ethanol.
• the Total acid number of the de-watered pyrolysis oil mixture is remarkably low relative to the Total acid number mixture of at least the pyrolysis oil present in the mixture comprising the pyrolysis oil and the high boiling hydrocarbon prior to evaporating water from the mixture.
• the Total acid number of the de-watered pyrolysis oil mixture may preferably be at most 20 % of the quotient A/B, wherein A represents the Total acid number of the pyrolysis oil and B represents the weight fraction of the pyrolysis oil in the mixture comprising the pyrolysis oil and the high boiling hydrocarbon prior to evaporating water from the mixture.
• the Total acid number of the de- watered pyrolysis oil mixture is at most 10 %, in particular at most 5 %, of the quotient A/B. Frequently, the Total acid number of the de-watered pyrolysis oil mixture is at least 0.01 %, or at least 0.1 %, of the quotient A/B.
• the low Total acid number of the high boiling hydrocarbon amounts preferably to at most 5 mg KOH/g, more preferably at most 1 mg KOH/g.
• the low Total acid number of the high boiling hydrocarbon may amount to at least 0.01 mg KOH/g, or at least 0.05 mg KOH/g.
• the Total acid number of the de-watered pyrolysis oil mixture may preferably be at most 15 mg KOH/g, more
• the low Total acid number of the de-watered pyrolysis oil mixture may amount to at least 0.05 mg KOH/g, or at least 0.1 mg KOH/g.
• the storage stability of the de-watered pyrolysis oil mixture as such, or blends comprising the de-watered pyrolysis oil mixture is remarkably good.
• said blends are made by blending the de-watered pyrolysis oil mixture with a high boiling hydrocarbon mixture as specified hereinbefore.
• the improvement in the storage stability is such that a skilled person may not consider the use of an emulsifier for stabilizing the de-watered pyrolysis oil mixture, or such blends.
• storage stability is measured by following the kinematic viscosity at 50 °C as measured according to ASTM D445 during storage at 50 °C .
• the value of the kinematic viscosity is constant or variable within at most 15 % of the value at the start of the storage, more preferably within 10 %, in particular with 5 % of the value at the start of the storage.
• the de-watered pyrolysis oil mixture may be used, as such, as a component of heavy fuel for marine and/or stationary applications.
• the present invention also provides a fuel product which is obtainable by a method for upgrading a pyrolysis oil as described herein, more specifically a fuel product which is obtainable by a method comprises combining in a mixture a pyrolysis oil and a hydrocarbon having an
• This "method comprising combining in a mixture a pyrolysis oil and a hydrocarbon having an atmospheric boiling point of at least 130 °C and evaporating water from the mixture” may be as described herein and the preferences for such a method may also be as described herein.
• the method preferably comprises combining in a mixture a pyrolysis oil and a hydrocarbon having an
• the fuel product is therefore preferably a fuel product having a water content of at most 5 %wt more preferably at most 2 %wt, and most preferably at most 1 %wt .
• the fuel product may have a solids content of at most 10 %wt, preferably at most 5 %wt, relative to the weight of the pyrolysis oil, wherein solids content is as measured by using the Hot filtration test according to ASTM D4870, modified in that the prescribed rinsing of the filter employed in the Hot filtration test is followed by rinsing with ethanol.
• the fuel product may have a kinematic
• kinematic viscosity measured at 50 °C which kinematic viscosity has a value which is constant within 15 %, preferably within 10 %, and most preferably within 5 %, relative to the value at the start of the storage, during storage of the fuel product at 50 °C for a period of 14 days, wherein kinematic viscosity is as measured according to ASTM D445.
• the fuel product may have a Total acid number (TAN) of at most 20 %,
• A represents the Total acid number of the pyrolysis oil
• B represents the weight fraction of the pyrolysis oil in the mixture comprising the pyrolysis oil and the high boiling hydrocarbon, wherein Total acid number is as measured by using ASTM D664.
• the de-watered pyrolysis oil mixture may be used, as such, as a component of heavy fuel for marine and/or
• the de-watered pyrolysis oil mixture may be used as a feedstock for
• hydrocarbon conversion processes such as hydrodeoxygenation thermal cracking, fluid catalytic cracking and
• the de-watered pyrolysis oil mixture may be used as such or may be further blended with a high boiling hydrocarbon or high boiling hydrocarbon mixture, as defined hereinbefore.
• the hydrocarbon conversion processes are, as such, known in the art. As an example, reference may be made to EP-A-2325281, which discloses a suitable fluid catalytic cracking process, including suitable conditions and
• the fluid catalytic cracking of a de-watered pyrolysis oil mixture is carried out whilst co-feeding or co-blending a further high boiling hydrocarbon or further high boiling hydrocarbon mixture with it.
• the de-watered pyrolysis oil mixture, and optionally any further high boiling hydrocarbons co-feeded or blended therewith is contacted during such fluid catalytic cracking with a fluid catalytic cracking catalyst at a temperature in the range from equal to or more than 480°C to equal to or less than 700°C, preferably in a riser reactor.
• the fluid catalytic cracking catalyst can be any catalyst known by the person skilled in the art to be suitable therefore.
• the product obtained in the hydrocarbon conversion process may suitably be separated into hydrocarbon product fractions, such as fractions comprising liquefied petroleum gas, gasoline, kerosene and/or diesel. Suitable separation methods, for example distillation, are known in the art. Such hydrocarbon product fractions are suitable for use as transportation fuel or as fuel for stationary application.
• the high boiling hydrocarbon mixture in examples 1 to 3 was a Kuwait Long Residue (further abbreviated as KLR) . This Kuwait Long Residue further had a Total Acid Number of about 0.14 mg KOH/g.
• the high boiling hydrocarbon mixture in example 4 was a Saudi Arabian Short Residue (further abbreviated as SASR) .
• SASR Saudi Arabian Short Residue
• the resultant mixture was placed in a round-bottom flask of a standard laboratory rotary evaporator. After attaching the flask to the rotary evaporator, an oil bath was placed around the flask and heated to 110 °C or 90 °C, while the flask was allowed to rotate.
• the C7-asphaltene content and initial boiling points (IBP) for the high boiling hydrocarbon mixture were as follows:
• SASR Saudi Arabian Short Residue
• the water fraction comprised a substantial quantity of organic acids, in particular formic acid, acetic acid, propionic acid, butyric acid and glycolic acid.
• a de-watered pyrolysis oil mixture was obtained from a mixture comprising 51.84 g of the same pyrolysis oil and 206.97 g of a blend comprising 170.66 g of a vacuum gas oil and 36.31 g of a Kuwait Long Residue (KLR) .
• the Kuwait Long Residue had an initial boiling point above 350°C and an asphaltene content of 4.2 %wt .
• This Kuwait Long Residue further had a Total Acid Number of about 0.14 mg KOH/g.
• the temperature of the oil bath was 110 °C .
• the water content of the de-watered pyrolysis oil mixture was 0.09 %wt .
• a sample of the de- watered pyrolysis oil mixture was subjected to catalytic cracking in a small-scale fluidized catalytic cracking reactor.
• a commercial equilibrium catalyst comprising ultra stable zeolite Y (USY) in an amorphous alumina matrix was used as the cracking catalyst.
• the cracking catalyst to oil ratio used was 4.31 to achieve 60 % conversion.
• the reaction temperature was kept at 520 °C and the pressure was kept at 120 kPa.
• the gas phase product was quantified and
• a de-watered pyrolysis oil mixture was obtained from a mixture comprising 10 %wt of the same pyrolysis oil and 90 %wt of a blend comprising 82.5 %wt of a vacuum gas oil and 17.5 %wt of the Kuwait Long Residue (KLR) of Example 5.
• a de-watered pyrolysis oil mixture was obtained from a mixture comprising 5 %wt of the same pyrolysis oil and 95 %wt of the Kuwait Long Residue (KLR) of Example 5.
• the temperature of the oil bath was 110 °C .
• the Total acid number of the de-watered pyrolysis oil mixture was 1.06 mg KOH/g. Based on the Total acid numbers of the individual components, the Total acid number of the pyrolysis oil mixture before de-watering was calculated to amount to 5 mg KOH/g.
• a de-watered pyrolysis oil mixture was obtained from a mixture comprising 10 %wt of the same pyrolysis oil and 90 %wt of the Kuwait Long Residue (KLR) of Example 5.
• the temperature of the oil bath was 110 °C .
• a water fraction was distilled off during a period of 1 hours.
• the Hot filtration test the de-watered pyrolysis oil mixture obtained was found to comprise 0.11 %wt insoluble material.
• the Hot filtration test was carried out according to ASTM D4870, modified in that the prescribed rinsing of the filter employed in the Hot filtration test is followed by rinsing with ethanol. In the same test, the Kuwait origin long residue was found to comprise 0.01 %wt insoluble material .
• a de-watered pyrolysis oil (comparative example A) or a de-watered pyrolysis oil mixture (Examples 9 - 14) was obtained from pyrolysis oil (comparative example A) or from a mixture comprising a pyrolysis oil and a high boiling hydrocarbon mixture (Examples 9 - 14) .
• the pyrolysis oil originated from Biomass Technology Group, Enschede, The Netherlands. Table II specifies the type of the high boiling hydrocarbon mixture, the intake of materials, the temperature of the oil bath, the pressure and the water content of the de-watered pyrolysis oil mixture obtained.
• the distillate mentioned in table II contains the water fraction that was evaporated, condensed and retrieved. In addition to the water, this distillate may contain condensed acids.
• examples 12 to 14 do allow for the formation of a mixture and does allow for the dewatering, these examples are less preferred as after dewatering, phase separation and solid formation may occur after a certain amount of time.
• a de-watered pyrolysis oil mixture similar to the de- watered pyrolysis oil mixture obtained in Example 9 was mixed with Residual fuel oil (RFO, with a C7-asphaltenes content of about 10 wt% and an initial boiling point of about 200°C) to obtain a mixture comprising 10 %wt pyrolysis oil, the balance being Residual fuel oil (Mixture A) .
• RFO Residual fuel oil
• Mixture B Residual fuel oil
• a de-watered pyrolysis oil mixture was obtained from a mixture comprising a high boiling hydrocarbon mixture and a pyrolysis oil as listed in table III.
• the temperature of the oil bath was kept at 110°C.
• a water fraction was distilled off during a period of 1 hour.
• the C7-asphaltene content and initial boiling points (IBP) for the components of the high boiling hydrocarbon mixture were as follows:
• DSR Dalia Short Residue
• BSR Bashra Short Residue
• VGO Vacuum Gas oil
• the dewatered mixtures were checked visibly on stability and on solids visible to the eye.

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