A method for treating liquefied biomass product stream

Abstract

Provided herein is a method for treating a liquefied biomass product stream, said method comprising: i) providing a liquefied biomass product stream comprising hydrocarbons, water and emulsifier(s), ii) subjecting the liquefied biomass product stream to a high pressure high temperature separation step (HPHT) to obtain a heavy oil fraction (A), and a HPHT separator gas fraction, iii) subjecting the HPHT separator gas fraction to a high pressure separation step to obtain a stream with an increased amount of emulsifier(s), wherein the high pressure separation step is a high pressure medium temperature (HPMT) separation step or a high pressure low temperature (HPLT) separation step.

Description

[0001]AMETHOD^FOR^TREATING^LIQUEFIED^BIOMASS^PRODUCT^STREAM FIELD OF THE INVENTION The present invention relates to a method of treating liquefied biomass product streams. In particular, the present invention relates a method of treating liquefied biomass product stream so as to avoid formation of an oil-in-water emulsion either by separating emulsifier(s) from the stream prior to the formation of the emulsion or by separating emulsified water and emulsifier(s) present in the liquefied biomass product stream into different fractions. BACKGROUND OF THE INVENTION When biomass-based materials, such as lignocellulosic materials, are liquefied using direct hydrogenation for production of biomass-based fuels and chemicals, the liquefaction product is usually a two-phase liquid mixture where the aqueous phase is an emulsion, that is, an emulsified aqueous phase. One of the problems associated with the liquefied biomass product streams, especially with lignocellulosic liquefied biomass product streams, is said oil-in-water emulsion which has been proven to be difficult to break as it is resistant to heating, cooling, freezing, centrifugation, and acid addition. Only base addition with impractical amounts of caustic have been able to break the emulsion. The present invention offers a method for preventing the formation of this oil-in-water emulsion and / or breaking the emulsion into an organic phase and a non-emulsified aqueous phase using the combination of different high pressure separation steps and / or distillation. Patent publication WO2012027428A1 discloses a method for treatment of bio-oil, and more specifically the processes and systems for reducing residual and bound water in bio-oil. BRIEF DESCRIPTION OF THE INVENTION An object of the present invention is thus to provide a method so as to solve the above problem. The objects of the invention are achieved by a method which is characterized by what is stated in the independent claims. The preferred embodiments of the invention are disclosed in the dependent claims. The invention is based on the realization that removing heavy compounds by distillation resulted in the breakage of the emulsion and as a result the light oil and the aqueous phase forming the emulsion were no longer an emulsion but two clear phases when condensed from distillation. An advantage of the method of the invention is that preventing and / or breaking the emulsion allows oil recovery with positive impact on carbon yield, improves wastewater properties with benefits for downstream treatment, and has a positive impact on instrument reliability. Provided herein is a method for treating a liquefied biomass product stream, said method comprising i) providing a liquefied biomass product stream comprising hydrocarbons, water and emulsifier(s), ii) subjecting the liquefied biomass product stream to a high-pressure high temperature separation step (HPHT) to obtain a heavy oil fraction (A) comprising heavy hydrocarbons and solids, and a HPHT separator gas fraction comprising light oil, water, emulsifier(s), and non-condensables, iii) subjecting the HPHT separator gas fraction to a high-pressure separation step to obtain at least a stream containing emulsifier(s) from said gas fraction, wherein the high-pressure separation step is a high-pressure medium temperature (HPMT) separation step such that the stream containing emulsifier(s) from said gas fraction is an oil stream (B), or wherein the high-pressure separation is a high-pressure low temperature (HPLT) separation step such that the stream containing emulsifier(s) from said gas fraction is an emulsified aqueous stream (C). In preferred embodiments the HPMT separation step is performed such that the process conditions are selected so that water does not condense. In another preferred embodiment, the HPLT separation step is performed such that the process conditions are selected so that water condenses. BRIEF DESCRIPTION OF THE DRAWINGS In the following the invention will be described in greater detail by means of preferred embodiments with reference to the accompanying drawings, in which Figure 1 depicts one possible embodiment of the current method. Figure 2 depicts one possible embodiment of the current method. Figure 3 depicts one possible embodiment of the current method. Figure 4 depicts one possible embodiment of the current method. Figure 5 depicts one possible embodiment of the current method. DETAILED DESCRIPTION OF THE INVENTION Liquefied biomass product streams typically comprise emulsifier(s) which typically results in a formation of an oil-in-water emulsion. Separation of water and the emulsifier(s) from this emulsion has been proven difficult as it is resistant to heating, cooling, freezing, centrifugation and acid addition. Only base addition with impractical amounts of caustic appeared to break the emulsion. An advantage of the method of the invention is that preventing and / or breaking the emulsion allows oil recovery with positive impact on carbon yield, improves wastewater properties with benefits for downstream treatment, and has a positive impact on instrument reliability. To solve the problem above, the method of this invention offers two alternative approaches. First approach involves separation and / or recovery of the emulsifier(s) from the liquefied biomass product stream before the formation ofthe oil-in-water emulsion, while the second approach involves breaking theemulsion after it has formed. One of the benefits of this method is improved carbon yield by minimizing carbon losses to wastewater. The “liquefied biomass product stream” herein refers to a product stream which has been obtained through liquefaction of biomass. The liquefied biomass product stream comprises hydrocarbons, water and emulsifier(s), such as oxygenates including organic acids. The oxygenates can include, for example, ketones, aldehydes, esters, and phenols. The liquefied biomass product stream may additionally comprise solids, which are often impurities such as char, coke and / or sand. The term “biomass” used herein includes, but is not limited to, algae, lignocellulosic biomass including lignocellulosic biomass components such as cellulose, hemicellulose and / or lignin. The process contemplated herein is particularly suitable and optimized for lignocellulosic biomass and its components. Lignocellulosic biomass is essentially made up of three natural polymers: cellulose, hemicellulose and lignin. The lignocellulosic starting material in the present invention can be of any types of lignocellulosic material. A non-exhaustive list of examples of the lignocellulosic material includes wood chips and / or saw dust with a dry content of 50 wt.-% or more; forestry residue chosen from bark, and / or roots, and / or branches with a dry content of 50 wt.-% or more; wood having been subjected to drying; lignocellulose from agriculture like for example straw from crops like oats, wheat, barley and rye, corn stover, grasses and herbs, forage crops, oat husks, rice husks, construction waste containing at least 50 wt.-% originating from lignocellulosic matter; and mixtures thereof. Prior to being fed to the hydroliquefaction step the biomass feedstock, may be grinded and / or dried as found suitable by a skilled person by any conventional means found suitable for the purpose to render it processable in the hydroliquefaction step. In the present invention, the term “renewable” indicates the presence of a material derived from renewable sources. Carbon atoms of renewable or biological origin comprise a higher number of unstable radiocarbon (14C) atoms compared to carbon atoms of fossil origin. Therefore, it is possible to distinguish between carbon compounds derived from renewable or biological sources or raw material and carbon compounds derived from fossil sources or raw material by analysing the ratio of 12C and 14C isotopes. Thus, a particular ratio of said isotopes can be used as a “tag” to identify renewable carbon compounds and differentiate them from non-renewable carbon compounds. The isotope ratio does not change in the course of chemical reactions. Examples of a suitable method for analysing the content of carbon from biological or renewable sources are DIN 51637, ASTM D6866 or EN 16640. As used herein, the content of carbon from biological orrenewable sources is expressed as the biogenic carbon content meaning theamount of biogenic carbon in the material as a weight percent of the total carbon (TC) in the material, as determined in accordance with ASTM D6866. A biogenic carbon content of the total carbon content in a product, which is completely of biological origin, may be about 100 percent. The biogenic carbon content of therenewable material (e.g. renewable co-feed) according to the invention is lower incases where other carbonaceous components besides biological components are used in the processing of the product but is preferably at least 5 percent. In one embodiment of the invention, the liquefied biomass product stream is liquefied lignocellulosic product stream. In the method according to the invention the liquefied biomass product stream is first subjected to a high-pressure high-temperature (HPHT) separation step (10) to obtain a heavy oil fraction (A) comprising heavy hydrocarbons and solids, and a HPHT separator gas fraction comprising light hydrocarbons, water, emulsifier(s), such as oxygenates including organic acids, and non-condensables, such as sour gases. Heavy oil fraction, comprising heavy hydrocarbons, is comprised of atleast 50% of components with boiling point above 290°C. The light oil comprises 90 % of the C4 and lighter boiling compounds. The solids in the heavy oil fraction (A) are often impurities such as char, coke and / or sand. The heavy oil fraction may be subjected to further treatment steps to separate the solids from the heavy oil. The exact composition of the emulsifier(s) causing the oil-in-water emulsion is not known in the art, but it was found out that there was a correlation between the formation of an emulsion and the presence of oxygenates such as ketones, aldehydes, esters, phenols, organic acids, and alcohols. Herein the term “non-condensables” refers to compounds and gases which do not condense in further treatment steps. This includes sour gases, such as but not limited to CO2and H2S, and gases such as H2, CO, methane, ethane and propane. In the HPHT separation step (10) the HPHT is preferably performed in a pressure range of 6 to 30 MPa, specifically from 7 to 16 MPa, more specifically from 8 to 14 MPa, given as gauge pressure. In the HPHT separation step (10) the HPHT is preferably performed ata temperature range of above 300 °C, preferably from 320 °C to 390 °C.In one embodiment the HPHT separation step (10) is performed at a pressure range of 6 to 30 MPa, specifically from 7 to 16 MPa, more specifically from8 to 14 MPa, given as gauge pressure and at a temperature range of above 300 °C,preferably from 320 °C to 390 °C.In the method according to the invention the HPHT separator gas fraction obtained from the HPHT step is then subjected to a high-pressure separation step to obtain at least a stream with an increased amount of emulsifier(s), and optionally at least one other stream. The high-pressure separation step is performed at a temperature which is different from the temperature used in the HPHT step. For example, the high-pressure separation step can be a high-pressure medium temperature (HPMT) treatment or a high-pressure low temperature (HPLT) treatment. In an embodiment the high-pressureseparation step comprises HPMT treatment and HPLT treatment. In an alternative embodiment the high-pressure separation step comproses HPLT treatment and does not comprise HPMT treatment, preferably in this embodiment the method further comprises subjecting the emulsified aqueous stream (C) to at least one distillation step. In case the high-pressure separation step is or comprises a high-pressure medium temperature (HPMT) separation step (15), the stream containing emulsifier(s) is an oil stream (B) containing an increased amount of emulsifier(s), and the optional at least one other stream obtained from the separation step includes a HPMT separation gas comprising light oil, water and non-condensables. Separation of the oil stream (B) containing an increased amount of emulsifier(s) from the HPMT separation gas prevents the formation of the oil-in-water emulsion, thereby eliminating the need for breaking the oil-in-water emulsion. In an embodiment, the HPMT separation step (15) is performed at apressure range of 6 to 30 MPa, specifically from 7 to 16 MPa, more specifically from 8 to 14 MPa, given as gauge pressure. In an embodiment the HPMT separation step (15) is performed in atemperature range of 250 to 300°C.In one embodiment the HPMT separation step (15) is performed at a pressure range of 6 to 30 MPa, specifically from 7 to 16 MPa, more specifically from 8 to 14 MPa, given as gauge pressure and at a temperature range of 250 to 300°C. In HPMT separation step, the process conditions are selected so thatwater does not condense. These specific process conditions of the HPMTseparation step improve removal of oil stream (B) containing an increased amount of emulsifier(s), which in turn results in improved removal of emulsifier(s) fromthe HPMT separation gas. This improved removal of emulsifier(s) prevents theformation of emulsions in downstream processing, which in turn makes furtherprocess steps (distillation, for example) easier and improves wastewaterproperties. Thus it was surprisingly found that in a following HPLT separation stepno or very low amount of emulsions are formed. The HPMT separation gas obtained from the HPMT separation step (15) can further be subjected to a high-pressure low temperature (HPLT) separation step (20) to obtain a non-emulsified aqueous stream, a light oil stream, and HPLT separator gas stream comprising non-condensables. One goal of the HPLT step is to separate an emulsified aqueous stream (C) in the form of an emulsion which can be subjected to further process steps to break the emulsion. The benefit of performing HPLT separation step (20) after HPMT separation step (15) is that it enables breakage of emulsion(s) which result from presence of left-over emulsifier(s) that might remain in the oil stream (B). In case the high-pressure separation step is a high-pressure low temperature (HPLT) (20) separation step, the stream containing emulsifier(s) is anemulsified aqueous stream (C). In the case that the HPHT is followed by HPLT,there is no HPMT separation step, and the optional at least one other stream includes a HPLT separator gas stream and optionally a light oil stream. The HPLT separation step (20) is performed at a pressure range of 6 to 30, specifically 7 to 16, more specifically 8 to 14, given as gauge pressure. In an embodiment the HPLT separation step (20) is performed at atemperature range of 20 to 150°C, specifically from 40 to 120°C, more specificallyfrom 60 to 100°C.In one embodiment the HPLT separation step (20) is performed at a pressure range of 6 to 30, specifically 7 to 16, more specifically 8 to 14, given asgauge pressure and at a temperature range of 20 to 150°C, specifically from 40 to120°C, more specifically from 60 to 100°C.In HPLT separation step (20) the process conditions are selected so that watercondenses. These specific process conditions result in improved removal of theemulsified aqueous stream (C). Improved removal of the emulsified aqueous stream (C) results in improved properties of the HPLT separator gas stream andthe optional light oil stream also obtained from the HPLT separation step. Theemulsified aqueous stream (C) is an emulsion comprising approximately 80 to 90 % of water and an increased amount of emulsifier(s). To break said emulsified aqueous stream (C) emulsion obtained from the HPLT separation step (20), the emulsified aqueous stream (C) can then be subjected to at least one distillation step. In one embodiment the at least one distillation step comprises a first distillation step (S1). In one embodiment the emulsified aqueous stream (C) in the form of an emulsion containing an increased amount of emulsifier(s) is subjected to a first distillation step S1. The first distillation step (S1) can take place in an arrangement comprising at least one distillation unit(s). For example, the distillation arrangement can comprise distillation column(s) and / or evaporator(s), etc. In this case the emulsified aqueous stream (C) is split into a distillation bottom stream (D) comprising predominantly hydrocarbons and emulsifier(s), and a S1 overhead stream (E) comprising predominantly water, light hydrocarbons and sour gases. In an embodiment the first distillation step (S1) splits the emulsified aqueous stream (C) into at least a distillation bottom stream (D) comprising predominantly hydrocarbons and emulsifier(s), and an overhead stream (E). In an embodiment of the invention the first distillation step (S1) takes place in a distillation arrangement, comprising at least one distillation unit, and said first distillation step (S1) splits the emulsion of the emulsified aqueous stream (C) into a distillation bottom stream (D) comprising predominantly hydrocarbons and emulsifier(s) and a S1 overhead stream (E). In this embodiment the non- emulsified aqueous stream (f) depleted of organics is not recovered from the first distillation unit of distillation step (S1). In one embodiment, the distillation bottom stream (D) obtained from the first distillation step (S1) can be combined with the heavy oil fraction (A). After the first distillation step (S1) the S1 overhead stream (E) can be further subjected to a condensing step and / or a gas separation step (30) to remove sour gases and to obtain a condensed stream (G). In one embodiment, the emulsified aqueous stream (C) is subjected to a first distillation step (S1) to obtain a distillation bottom stream (D) comprising heavy oil, emulsifier (s) and less than 1 % of water, and a S1 overhead stream (E) comprising water, light oil and sour gases. The S1 overhead stream (E) is then subjected to a gas separation step and / or a condensation step (30), to obtain a condensed stream (G). The condensed stream (G) is then subjected to a decanting step (40) to separate an organic phase (41) and a non-emulsified aqueous phase (42) to obtain an oil product stream (I) and a non-emulsified aqueous stream (J). In this embodiment the non-emulsified aqueous stream (J) will contain sour gases. The non-emulsified aqueous stream (J) can then be routed to normal sour gas treatment. In this embodiment the oil product stream (I) comprises light oil and less than 1 % of water. The at least one distillation step can further involve a second distillation step (S2). Optionally the at least one distillation step can further involve a second distillation step (S2) and a third distillation step (S3). In an embodiment the at least one distillation step comprises a first distillation step (S1) and a second distillation step (S2). In an embodiment the at least one distillation step comprises a first distillation step (S1), a second distillation step (S2) and a third distillation step (S3). The S1 overhead stream (E) obtained from the first distillation step (S1) can be subjected to a second distillation step (S2) to obtain at least a non-emulsified aqueous stream (f) depleted of organics, and a S2 overhead stream (F) comprising water, organics, and sour gases. In an embodiment the emulsified aqueous stream (C) is first subjected to a first distillation step (S1) to obtain a distillation bottom stream (D) comprising heavy oil, emulsifier(s) and less than 1 % of water, and a S1 overhead stream (E) comprising water, light oil and sour gases. The S1 overhead stream (E) is then subjected to a second distillation step (S2) to obtain a S2 overhead stream (F) comprising light oil, sour gas and some water, and a non-emulsified aqueous stream (f) depleted of organics comprising less than 5 % of organics. The S2 overhead stream (F) can then be subjected to a gas separation step and / or condensing step (30) to obtain a sour gas stream (H) comprising sour gases, such as CO2and S2H, and a condensed stream (G). The condensed stream (G) can then be subjected to a decanting step (40) to separate a non-emulsified aqueous phase (42) and an organic phase (41) to, respectively, obtain a non-emulsified aqueous stream (J), which is essentially a S2 reflux comprising mainly water, and an oil product stream (I). The oil product stream (I) can optionally be subjected to a third distillation step (S3) to obtain light oil comprising less than 1 % water and to obtain light oil free of sour gases. In an embodiment the overhead stream (E) obtained from the first distillation step (S1) is subjected to a second distillation step (S2) to obtain at least a non-emulsified aqueous stream, and a S2 overhead stream (F) comprising water and organics, and sour gases such as CO2, H2S, wherein the first distillation step(S1) and the second distillation step (S2) take place in separate individual units.The first distillation step (S1) and the second distillation step (S2) can take place in a single distillation step (S) in a single unit, which can, for example, be a divided wall column, furthermore a feed inlet can be configured above a water outlet. In this case, the emulsified aqueous stream (C) is split into the distillation bottom stream (D) comprising predominantly hydrocarbons and emulsifier(s), a distillation overhead stream (E1) comprising predominantly light oil and sour gases, and a non-emulsified aqueous stream (f) depleted of organics, comprising water and less than 5 % of organics. If the distillation step (S) is performed in a conventional distillation column, a further distillation step might be required to obtain a non-emulsified aqueous stream (f) depleted of organics. However, using a divided wall column makes it possible to obtain the non-emulsified aqueous stream (f) depleted of organics without having to perform a further distillation step. Herein the term “depleted of organics” refers to a stream / streams in which the content of organics is less than 5 %. In an embodiment of the invention the distillation step (S) takes place in a divided wall column and said distillation splits the emulsion of the emulsified aqueous stream (C) into the distillation bottom stream (D) comprising predominantly hydrocarbons and emulsifier(s), a non-emulsified aqueous stream depleted of organics, and a S overhead stream (E1) comprising predominantly light hydrocarbons and sour gases. In this embodiment a further distillation step is not required. In one embodiment the emulsified aqueous stream (C) is subjected to a first distillation step (S1) to obtain a distillation bottom stream (D) comprising predominantly hydrocarbons and emulsifier(s), and a S1 overhead stream (E) comprising predominantly water, light hydrocarbons and sour gases. The obtained S1 overhead stream (E) is then subjected to a second distillation step (S2) to obtain at least a non-emulsified aqueous stream (f) depleted of organics, and a S2 overhead stream (F) comprising water and organics, and sour gases. S2 overhead stream (F) can further be subjected to a gas separation step and / or condensing step (30) to obtain a condensed stream (G) and a sour gas stream (H). This gas separation step can, for example, be performed using a condenser. After distillation and condensation there is no longer emulsion in the aqueous phase. In an embodiment, the overhead stream (E, E1, F) is subjected to at least a condensing step and / or a gas separation step (30) to obtain at least a condensed stream (G) and / or a sour gas stream (H), respectively. The obtained condensed stream (G) can further be subjected to a decanting step (40) to separate non-emulsified aqueous phase (42) and an organic phase (41) to obtain a non-emulsified aqueous stream (J) and an oil product stream (I) respectively. The obtained non-emulsified aqueous stream (J) comprises mostly water, while the obtained oil product stream (I) comprises organics. The non- emulsified aqueous stream (J) can be subjected to wastewater treatment steps or be recycled back to a distillation step. In one embodiment, the condensed stream (G) is subjected to a decanting step (40) to obtain an oil product stream (I) and a non-emulsified aqueous stream (J). In one embodiment the non-emulsified aqueous stream (J) is recirculated to at least one distillation step. In one embodiment the condensed stream (G) contains sour gases, and the decanting step is a multiple-phase separation step such that the decanting step and gas separation step take place in a single unit, preferably a decanter unit. The oil product stream (I) obtained from the decanting step (40) can then optionally be subjected to a third distillation step (S3) to obtain a light oil stream without sour gases (K) comprising mostly light oil and only < 1 % water. The combined overhead product stream from S3 and S2 overhead stream (F) can then be subjected to the gas separation step and / or condensing step (30). The purpose of the third distillation step is to separate azeotropes and / or strip off the sour gases from the light oil to meet product quality. In one embodiment the oil product stream (I) is further subjected to a third distillation step (S3) to obtain a light oil stream (K) depleted of sour gases. In one embodiment the overhead stream of the third distillation step S3 is further subjected to at least a gas separation step and / or a condensing step or is recycled to be combined with a previous overhead stream (E, E1, F) before being subjected to at least a gas separation step and / or condensing step. Figure 1 depicts an embodiment of the invention wherein liquefied biomass product stream (1) is first subjected to a high-pressure high temperature (HPHT) separation step (10) to obtain a heavy oil fraction (A) and a HPHT separator gas fraction which is subjected to a high-pressure medium temperature (HPMT) separation step (15) to obtain an oil stream (B) with an increased amount of emulsifier(s), and a HPMT separator gas stream, comprising light oil, water and non-condensables. The HPMT separator gas stream is then subjected to a high- pressure low temperature (HPLT) treatment step (20). Figure 2 depicts an embodiment of the invention wherein liquefied biomass product stream (1) is subjected to a high-pressure high temperature (HPHT) treatment step (10) to obtain a heavy oil fraction (A) and a HPHT separator gas fraction which is subjected to a high-pressure low temperature (HPLT) separator step (20) to obtain an emulsified aqueous stream (C). Figure 3 depicts an embodiment of the invention wherein the emulsified aqueous stream (C) is subjected to a first distillation step (S1) to obtain distillation bottom stream (D) and a S1 overhead stream (E). The S1 overheadstream (E) is then subjected to a second distillation step (S2) to obtain a S2overhead stream (F) and a non-emulsified aqueous stream (f). The S2 overhead stream (F) is then subjected to a gas separation step and / or condensing step (30), to obtain a sour gas stream (H) and a condensed stream (G). Condensed stream is then subjected to a decanting step (40) to separate organic phase (41) and the non-emulsified aqueous phase (42), to obtain an oil product stream (I) and a non-emulsified aqueous stream (J), respectively. The non-emulsified aqueous stream (J) can optionally be recycled back to the second distillation step (S2), and the oil product stream (I) can optionally be subjected to a third distillation step (S3) to obtain the light oil product without sour gases (K). Figure 4 depicts an embodiment of the invention, wherein the emulsified aqueous stream (C) is subjected to a distillation step (S) in a single unit, preferably a divided wall column in which a feed inlet is configured above a water outlet, to obtain a distillation bottom stream (D) comprising heavy oil and emulsifier, a non-emulsified aqueous stream (f) comprising less than 5 % organics, and a distillation overhead stream (E1). The distillation overhead stream (E1) is then subjected to a gas separation step and / or condensing step (30) to obtain a sour gas stream (H) comprising CO2and H2S, and a condensed stream (G) comprising light oil and less than 1 % of water. The condensed stream (G) can optionally be recycled back to the distillation unit for another distillation step (S). Figure 5 depicts an embodiment of the invention, wherein the emulsified aqueous stream (C) is subjected to a first distillation step (S1) to obtain a distillation bottom stream (D) comprising heavy oil and emulsifier(s), and S1 overhead stream (E). No separate non-emulsified aqueous stream (f) is recovered from the distillation step. The S1 overhead stream (E) is subjected to a gas separation step, for example, condensation step, to obtain a condensed stream (G). This condensed stream (G) is then subjected to a decanting step to separate an organic phase (41) and a non-emulsified aqueous phase (42), to obtain an oil product stream (I) and a non-emulsified aqueous stream (J), respectively. It will be obvious to a person skilled in the art that, as the technology advances, the inventive concept can be implemented in various ways. The invention and its embodiments are not limited to the examples described abovebut may vary within the scope of the claims.EXAMPLES Catalytic hydroliquefaction experiments have been carried out with sawdust and fossil co-feed in continuous mode. The product obtained consisted of heavy oil fraction, light oil fraction, emulsion fraction and gases. The emulsion has been observed in various liquefaction process conditions, but the samples used in this example have been produced in following conditions: NiMoS catalyst, 350 °C, 132 bar, 1 h residence time in stirred tank reactor. The feed of sample 1 consisted of 20% sawdust in heavy gas oil, NiMoS catalyst and H2, whereas the feed of sample 2 consisted of 10% of sawdust in heavy product of the process that has been recirculated 6 times through the reactor, NiMoS catalyst and H2. The two emulsion samples obtained from above according to present invention simulating the HPLT step and representing the emulsified aqueous stream (C) were distilled to break the emulsion. The amounts of fractions obtained in the distillations are presented in table 1. It was surprisingly observed that the emulsion is broken when distilling. The <100 °C fraction, separated spontaneously to two phases after distillation: organic and non-emulsified aqueous phase. The same happened to the fraction boiling at 100 °C. Table 1.

Claims

CLAIMS 1. A method for treating a liquefied biomass product stream, said method comprising i) providing a liquefied biomass product stream comprising hydrocarbons, water and emulsifier(s), ii) subjecting the liquefied biomass product stream to a high-pressure high temperature separation step (HPHT) to obtain a heavy oil fraction (A) comprising heavy hydrocarbons and solids, and a HPHT separator gas fraction comprising light oil, water, emulsifier(s), and non-condensables, iii) subjecting the HPHT separator gas fraction to a high-pressure separation step to obtain at least a stream containing emulsifier(s) from said gas fraction, wherein the high-pressure separation step is a high-pressure medium temperature (HPMT) separation step such that the stream containing emulsifier(s) from said gas fraction is an oil stream (B), or wherein the high-pressure separation is a high-pressure low temperature (HPLT) separation step such that the stream containing emulsifier(s) from said gas fraction is an emulsified aqueous stream (C).

2. A method according to claim 1, said method comprising i) providing a liquefied biomass product stream comprising hydrocarbons, water and emulsifier(s), ii) subjecting the liquefied biomass product stream to a high-pressure high temperature separation step (HPHT) to obtain a heavy oil fraction (A) comprising heavy hydrocarbons and solids, and a HPHT separator gas fraction comprising light oil, water, emulsifier(s), and non-condensables, iii) subjecting the HPHT separator gas fraction to a high-pressure separation step to obtain at least a stream containing emulsifier(s) from said gas fraction, wherein the high-pressure separation step is a high-pressure medium temperature (HPMT) separation step such that the stream containing emulsifier(s) from said gas fraction is an oil stream (B), wherein the HPMT separation step is performed such that the process conditions are selected so that water does not condense, or wherein the high-pressure separation is a high-pressure low temperature (HPLT) separation step such that the stream containing emulsifier(s) from said gas fraction is an emulsified aqueous stream (C), wherein the HPLTseparation step is performed such that the process conditions are selected so that water condenses.

3. The method according to claim 1 or 2, wherein the HPHT separationstep is performed at a pressure range of 6 to 30 MPa, specifically from 7 to 16 MPa, more specifically from 8 to 14 MPa, given as gauge pressure.

4. The method according to any one of the preceding claims, wherein the HPHT separation step is performed at a temperature range of above 300°C, more preferably from 320 to 390°C.

5. The method of any one of the preceding claims, wherein the liquefied biomass product stream is a liquefied lignocellulosic product stream.

6. The method according to any one of the preceding claims, wherein the high-pressure medium temperature (HPMT) separation step Further comprises at least one other stream, wherein said other stream is a HPMT separator gas stream comprising light oil, water, and non-condensables.

7. The method according to claim 6, wherein the HPMT separator gas stream comprising light oil, water, and non-condensables is subjected to a high- pressure low temperature (HPLT) separation step to obtain at least a non- emulsified aqueous stream, a light oil stream and a HPLT separator gas stream comprising non-condensables.

8. The method according to any one of the preceding claims, wherein the high-pressure medium temperature (HPMT) separation step is performed at a pressure range of 6 to 30 MPa, specifically from 7 to 16 MPa, more specifically from 8 to 14 MPa, given as gauge pressure.

9. The method according to any one of the preceding claims, wherein the high-pressure medium temperature (HPMT) separation step is performed at a temperature range of 250 to 300°C.

10. The method according to any one of the preceding claims, wherein the high-pressure low temperature (HPLT) separation step is performed at a pressure range of 6 to 30 MPa, specifically 7 to 16 MPa, more specifically from 8 to 14 MPa, given as gauge pressure.

11. The method according to any one of the preceding claims, wherein the high-pressure low temperature (HPLT) separation step is performed at a temperature range of 20 to 150°C, specifically from 40 to 120°C, more specifically from 60 to 100°C.

12. The method according to any one of claims 1 to 5, wherein the high- pressure separation step is a high-pressure low temperature (HPLT) separationstep, and wherein the emulsified aqueous stream (C) is further subjected to at least one distillation step.

13. The method according to claim 12, wherein the at least one distillation step comprises a first distillation step (S1).

14. The method according to claim 13, wherein the first distillation step (S1) splits the emulsified aqueous stream (C) into at least a distillation bottom stream (D) comprising hydrocarbons and emulsifier(s), and a S1 overhead stream (E).

15. The method according to claim 13 or 14, wherein the distillationstep further comprises a second distillation step (S2).

16. The method according to claim 14 or 15, wherein the S1 overheadstream (E) obtained from the first distillation step (S1) is subjected to the second distillation step (S2) to obtain at least a non-emulsified aqueous stream, and a S2 overhead stream (F) comprising water and organics, and sour gases, such as CO2, H2S, wherein the first distillation step (S1) and the second distillation step (S2) take place in separate individual units.

17. The method according to claim 15, wherein the first distillation step (S1) and the second distillation step (S2) take place in a single unit as distillation step (S), and said distillation step splits the emulsified aqueous stream (C) to obtain at least a distillation bottom stream (D) comprising predominantly hydrocarbons and emulsifier(s), a non-emulsified aqueous stream, and an overhead stream (E1) comprising predominantly light oil and sour gases respectively.

18. The method according to any one of the preceding claims, wherein the distillation bottom stream (D) is combined with the heavy oil fraction (A).

19. The method according to any one of the preceding claims, wherein the overhead stream (E, E1, F) is subjected to at least a condensing step and / or a gas separation step to obtain at least a condensed stream (G) and / or a sour gas stream (H) respectively.

20. The method according to claim 19, wherein the condensed stream (G) is subjected to a decanting step to obtain an oil product stream (I) and a non- emulsified aqueous stream (J).

21. The method according to claim 20, wherein the condensed stream (G) contains sour gases, and the decanting step is a multiple-phase separation step such that the decanting step and gas separation step take place in a single unit, preferably a decanter unit.

22. The method according to claim 20 or 21, wherein the non-emulsifiedaqueous stream (J) is recirculated to at least one distillation step.

23. The method according to any one of claims 20 to 22, wherein the oilproduct stream (I) is further subjected to a third distillation step to obtain a light oil stream (K) depleted of sour gases. (K).

24. The method according to claim 23, wherein the Overhead of the third distillation step (S3) is subjected to at least a condensing step and / or a gas separation step, or is recycled to be combined with an overhead stream before being subjected to at least a condensing step and / or a gas separation step.

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