Jet fuel component

Abstract

A renewable jet fuel component has a total iso-paraffin content of up to 90 wt.%, a C7-C14 paraffins content of at least 40 wt.%, a C15-C18 paraffins content of at most 60 wt.%, a C17-C18 paraffins content of at most 40 wt.%, a C18 paraffins content in a range of from 2 to10 wt.%, a >C18 paraffins content of at most 1 wt.%, wherein the iso-paraffin branching is such that a weight ratio of the sum of wt.% amounts of paraffins with more than 2 branches, to a sum of wt.% amounts mono-branched paraffins, is in a range from 1 to 2, wherein the ratio of total iso-paraffins to n-paraffins is more than 11.2, and wherein the renewable jet component has a freezing point of less than -60°C, a flashpoint of 40°C or more and a density of 770 kg / m3 or less.

Description

JET FUEL COMPONENTFIELD OF THE INVENTION

[0001] The present invention relates to a renewable jet fuel component, a process for preparing the renewable jet fuel component and jet fuel compositions comprising the renewable jet fuel component. In particular, the present invention relates to a renewable jet fuel component having a low freezing point and a high flashpoint.BACKGROUND OF THE INVENTION

[0002] Jet aircraft are typically exposed to very low operating temperatures during flight and therefore it is necessary that the fuel used in said aircraft does not freeze at these low temperature conditions. The freezing point of jet fuel is the lowest temperature at which the fuel remains free of solid hydrocarbon crystals that may restrict the flow of the fuel through filters in the fuel system of the engine. If the freezing point of the fuel is not low enough, blocking of fuel filters and problems with fuel pumpability can result. Hence, the freezing point of the fuel needs to be lower than the minimum fuel tank temperature experienced during flight conditions. The Jet A fuel specification sets a maximum freezing point for Jet A fuel of -40°C, while the Jet A-l fuel specification requires a maximum freezing point for Jet A-l fuel of -47°C as specified in ASTM D1655, while Jet B specification sets amaximum freezing point -50°C, as specified in ASTM D6615.

[0003] US 11,613,718 B2 relates to a multipurpose fuel composition which contains a petroleum derived jet fuel component and a renewable jet fuel component, wherein the multipurpose fuel composition has a freezing point of -40°C or below. The renewable jet fuel components disclosed in Tables 2, 3, 4 and 7 of US 11,613,718 B2 have measured freezing points of -31.5, -50.9, -51.8 and -31.5 respectively, respectively, and lower freezing points are only achieved by blending the renewable jet fuel component with petroleum derived jet fuel components. No reference is made to the flash point of these renewable jet fuel components.

[0004] WO 2022 / 008534 Al relates to improved freezing points in jet fuel compositions containing a petroleum derived jet fuel component and a renewable jet fuel component. The renewable jet fuel components disclosed in Table 2 of WO 2022 / 008534 Al have measuredfreezing points of -46.0°C, -33.0°C, -41.0°C, -46.0°C and -54.0°C via ASTM D2386-19. Lower freezing points are only achieved by blending the renewable jet fuel component with petroleum derived jet fuel components. No reference is made to the flash point of these renewable jet fuel components.

[0005] WO 2023 / 154715 Al discloses a heavy renewable jet fuel composition with a low freezing point. Table 2 discloses a renewable jet fuel component with a freezing point of -66°C and a flash point greater than 43°C, but is composed of heavy paraffins, comprising 55% products with 17 and more carbon atoms per molecule, and comprising 86% products with 14 and more carbon atoms per molecule, and a total iso-paraffins content of 90% or more.

[0006] WO 2017 / 197017 Al discloses a renewable jet fuel composition with an improved flash point. The renewable jet fuel composition is comprised of 98% C7-C12 n- paraffins, however the only low temperature property disclosed can be found in composition A of example 2, with a flash point of 51.9°C and a cloud point -20.9°C, with no reference to the freezing point of the composition.

[0007] Aalto et al. (FI20225609A1, 2024-01-02) describes providing a paraffinic hydrocarbon feed containing at least 5 wt.% isoparaffins to a first reaction section for hydrocracking the feed. The hydrocracking effluent is passed to a second reaction section for hydroisomerization. The hydroisomerization effluent is fractionated to produce a liquid transportation fuel. In the same family, FI130640B1 describes an aviation fuel component, comprising n-paraffins, monobranched i-paraffins and multiple-branched i-paraffins. The sum amount of C6-C18 n-paraffins, C6-C18 monobranched i-paraffins, and C6-C18 multiple-branched i-paraffins is at least 90 wt.% of the total aviation fuel component weight, wherein the weight ratio of C6-C18 multiple-branched i-paraffins to C6-C18 n-paraffins is at least 10, and wherein the amount of C14-C18 multiple-branched i-paraffins is at least 35 wt.%. The T10 and T90 temperatures are in a range from 120- 295 °C and the difference between T90 and T10 temperatures is at least 15 70°C.

[0008] Xu et al. (US2024 / 0002737A1, 2024-01-04) relates to single stage renewable jet production. A bio-derived feedstock is combined with a hydrocracked dewaxed co-feed to be contacted with a hydrotreating catalyst to produce a deoxygenated effluent The deoxygenated effluent is separated into a jet boiling range fraction and a second fraction having a boiling point of 300°C or higher. The second fraction is contacted with ahydrocracking catalyst to produce a hydrocracked effluent, which us contacted with a dewaxing catalyst to produce the hydrocracked dewaxed co-feed.

[0009] FR3134111A1 relates to a kerosene base comprising at least 60.0 wt.% of a mixture of C3n hydrocarbons and C4n hydrocarbons, with n being a natural number chosen between 3 and 4, in which at least 80 wt.% of the total weight of the kerosene base are isoparaffins.

[0010] It would be desirable to produce a renewable jet fuel component having improved (lower) freezing points, without having to blend with petroleum derived jet fuel components.

[0011] It would also be desirable to improve other properties of a renewable jet fuel component, in particular the flash point. The flash point of a chemical substance is the lowest temperature at which the substance will produce vapours in sufficient quantity to form an ignitable vapour / air mixture under specific standardized conditions. The higher the vapour pressure, the lower the flash point. The most common jet fuels in commercial use are Jet A and Jet A-l which are kerosene grade fuels having a minimum flashpoint of 38°C. From a safety viewpoint, it is preferably for jet fuels to have a high flash point so that they are much harder to accidentally ignite, making them safe for use in public spaces such as an airport.

[0012] Therefore, it would be desirable to produce renewable jet fuel components having improved (lower) freezing points, and preferably improved (higher) flash points, without having to blend with petroleum derived jet fuel components.SUMMARY OF THE INVENTION

[0013] According to one aspect of the present invention, there is provided a renewable jet fuel component comprising: a total iso-paraffin content of up to 90 wt.%, a C7-C14 paraffins content of at least 40 wt.%, a C15-C18 paraffins content of at most 60 wt.%, a C17- C18 paraffins content of at most 40 wt.%, a Cl 8 paraffins content in a range of from 2 to 10 wt.%, a >C 18 paraffins content of at most 1 wt.%, wherein the iso-paraffin branching is such that a weight ratio of the sum of wt.% amounts of paraffins with more than 2 branches, to a sum of wt.% amounts mono-branched paraffins, is in a range from 1 to 2, wherein the ratio of total iso-paraffins to n-paraffins is more than 11.2, and wherein the renewable jet component has a freezing point of less than -60°C, a flashpoint of 40°C or more and a density of 770 kg / m3or less.

[0014] It has been found that the renewable jet fuel component of the present invention has an improved (reduced) freezing point. At the same time, it has been found that therenewable jet fuel component of the present invention preferably has an improved (increased) flash point. The freezing point of the renewable jet fuel component of the present invention is -60°C or less, preferably -61°C orless, more preferably -63°C or less, even more preferably -65°C or less (as measured according to ASTM D5972). The flash point of the renewable jet fuel component of the present invention has a flashpoint of 40°C or more, preferably 42°C or more, (as measured according to ASTM D93).

[0015] According to another aspect of the present invention, there is provided a process for preparing the renewable jet fuel component described herein comprising the steps of (i) reacting a renewable feedstock in a hydrotreating zone in the presence of a hydrotreating catalyst to produce a hydrotreated effluent, (ii) reacting at least a portion of the hydrotreated effluent in a hydrocracking zone in the presence of a hydrocracking catalyst to produce a cracked effluent, (iii) reacting the cracked effluent in a hydroisomerization zone in the presence of a hydroisomerization catalyst to produce an isomerized effluent; (iv) separating the isomerized effluent to produce an offgas stream, at least one fuel stream having a kerosene boiling point range, to produce a renewable jet fuel component, and a heavy fraction having a boiling point greater than the kerosene boiling point range; and (v) recycling at least a portion of the heavy fraction to the hydrocracking zone.

[0016] According to yet another aspect of the present invention, there is provided a jet fuel composition comprising the renewable jet fuel component described herein.

[0017] According to a further aspect of the present invention, there is provided a use of the renewable jet fuel component described herein for reducing the freeze point of a petroleum-derived kerosene.

[0018] According to yet a further aspect of the present invention, there is provided a method for reducing the freeze point of a petroleum-derived kerosene by blending of at least 1% the renewable jet fuel component described herein with a petroleum-derived kerosene having a freeze point of greater than -60°C.DEFINITIONS

[0019] Renewable fuels, such as the renewable jet fuel component, are collected from resources, which are naturally replenished on a human timescale, as opposed to fossil fuels, such as petroleum-derived jet fuel, which are derived from the refining of crude oil. By the term renewable jet fuel component as used herein is meant a jet fuel / kerosene fraction which contains bio-based carbon atoms as determined according to ASTM method D6866-10entitled “Standard Test Methods for Determining the Biobased Content of Solid, Liquid and Gaseous samples using Radiocarbon Analysis.” The renewable content may then be determined by isotopic distribution involving14C,13C and / or12C as described in ASTM D6866.

[0020] The jet fuel component of the present invention is kerosene component. As used herein, the term “kerosene” means hydrocarbons or oxygenated hydrocarbons recovered by distillation between an atmospheric equivalent initial boiling point (IBP) and a final boiling point (FBP) measured according to standard ASTM distillation methods. ASTM D86 initial boiling point of kerosenes may vary between approximately 130°C to approximately 210°C. Final boiling point of kerosenes, according to ASTM D86, may vary from approximately 240°C to approximately 315°C.

[0021] The term “middle distillates” as used herein are hydrocarbons or oxygenated hydrocarbons recovered by distillation between an atmospheric-equivalent initial boiling point (IBP) and a final boiling point (FBP) measured according to standard ASTM distillation methods. ASTM D86 initial boiling point of middle distillates may vary from approximately 150°C to approximately 220°C. Final boiling point of middle distillates, according to ASTM D86, may vary from approximately 350°C to approximately 380°C.

[0022] As used herein, the term “naphtha” as used herein is one or more hydrocarbons or oxygenated hydrocarbons having four or more carbon atoms and having an atmospheric- equivalent final boiling point that is greater than approximately 90°C, but less than approximately 200°C. A small amount of hydrocarbons produced in the process (approximately less than 3 wt.% of total C4+ hydrocarbons, and preferably less than 1 wt.% of total C4+ hydrocarbons) boil at temperatures higher than those for the middle distillates as defined above. That is, these hydrocarbons have a boiling range similar to vacuum-gasoil produced by distillation of petroleum. Gasoline is predominantly naphtha-range hydrocarbons and is used in spark-ignition internal combustion engines. In the United States, ASTM D4814 standard establishes the requirements of gasoline for ground vehicles with spark ignition internal combustion engines. Gasoil (GO)Zdiesel is predominantly middle distillate range hydrocarbons and is used in compression-ignition internal combustion engines. In the United States, ASTM D975 standard covers the requirements of several grades of diesel fuel for various types of diesel engines.

[0023] The term “paraffins” as used herein means cyclic, non-cyclic, branched or unbranched alkanes. An unbranched paraffin is an n-paraffin; a branched paraffin is an iso-paraffin. “Cycloparaffins” are cyclic alkanes and can also be described further as branched or unbranched cyclic alkanes. Cycloparaffins can also be referred to as naphthenes or naphthenics. The term “paraffinic” as used herein means both paraffins and cycloparaffins as defined above as well as predominantly hydrocarbon chains possessing regions that are alkane, either branched or unbranched, with mono-, di-, tri-, tetra- or more unsaturation (i.e. one, two, three, four or more than two double bonds).DETAILED DESCRIPTION OF THE INVENTION

[0024] The renewable jet fuel component of the present invention is primarily paraffinic and comprises a mixture of iso-paraffins, n-paraffins, cyclo-paraffins and only a minor amount of other compounds.

[0025] The renewable jet fuel component of the present invention comprises a C7-C14 paraffins content of at least 40 wt.%, preferably in the range from 40 wt.% to 70 wt.%, more preferably in the range from 40 wt.% to 60 wt.%, by weight of the total renewable jet fuel component. In one embodiment, the renewable jet fuel component comprises 45 wt.% to 55 wt.% of C7-C14 paraffins, by weight of the total renewable jet fuel component.

[0026] The renewable j et fuel component of the present invention comprises a C 15-C 18 paraffins content of at most 60 wt.%, preferably in the range from 40 wt.% to 60 wt.%, more preferably in the range from 40 wt.% to 55 wt.%, by weight of the total renewable jet fuel component. In one embodiment, the renewable jet fuel component comprises from 46 wt.% to 55 wt.% of C15-C18 paraffins, by weight of the total renewable jet fuel component.

[0027] The renewable jet fuel component of the present invention comprises a C17-C18 paraffins content of at most 40 wt.%, preferably in the range from 1 wt.% to 40 wt.%, more preferably in the range from 10 wt.% to 40 wt.%, by weight of the total renewable jet fuel component. In one embodiment, the renewable jet fuel component comprises from 15 to 40 wt.% of Cl 7-C 18 paraffins, by weight of the total renewable jet fuel component.

[0028] The renewable jet fuel component comprises a Cl 8 paraffins content in a range of from 2 to 10 wt.%, based on the weight of the total renewable jet fuel component.

[0029] The renewable jet fuel component of the present invention comprises a content of paraffins having greater than 18 carbon atoms of at most 1 wt.%, based on the weight of the total renewable jet fuel component.

[0030] The iso-paraffin branching of the renewable jet fuel component of the present invention is such that a weight ratio of the sum of wt.% amounts of paraffins with more than 2 branches, to a sum of wt.% amounts mono-branched paraffins, is in a range from 1 to 2.

[0031] Preferably, no more than 10, 4.8 and 0.1 wt.% of the C15, C16 and C17 paraffins respectively, when considered individually, are normal paraffins, based on the weight of the C15 or C16 or C17 paraffins, respectively.

[0032] In one embodiment herein, the jet fuel component comprises from 10 wt.% to 25 wt.%, preferably from 10 wt.% to 20 wt.%, more preferably from 12 wt.% to 20 wt.%, even more preferably 16 wt.% to 20 wt.%, of C7-C10 paraffins, based on the total weight of the jet fuel component.

[0033] In a preferred embodiment herein, the C9, CIO, Cll, Cl 2, C13 paraffins, when considered independently as sub-groups, each make up at least 5 wt.% of the total renewable jet fuel component, and wherein the factor of increase of the smallest wt.% of these subgroups as compared to the largest wt.% is from 1 to 2.2, more preferably from 1 to 2, even more preferably from 1 to 1.8, and especially from 1.05 to 1.67.

[0034] The renewable jet fuel component of the present invention comprises a total isoparaffin content of up to 90 wt.%. In the renewable jet fuel component, the total amount of iso-paraffins is preferably more than 80 wt.%, more preferably more than 85 wt.%, even more preferably more than 87 wt.%, based on the renewable jet fuel component. The amount of n-paraffins in the renewable jet fuel component is preferably less than 20 wt.%, more preferably less than 15 wt.%, even more preferably less than 10 wt.%, based on the renewable jet fuel component. The amount of n-paraffins is preferably at least 3 wt.%, more preferably at least 5 wt.%. It is particularly surprising to achieve such a low a freezing point of -60°C or below given the content of iso-paraffins is at most 90 wt.%.

[0035] The paraffins in the renewable jet fuel component have an average carbon number in the range from 12 to 14, more preferably from 12.5 to 14, even more preferably from 12.9 to 14. The average carbon number can be calculated using the method below:1. Calculate the molecular weight of the corresponding paraffin (alkane) using the formula: CnH2n+2. For example, for butane, a C4 molecule: C4H10. Then multiply the C number with the atom weight of Carbon (12.01) and multiply the H number with 1. For butane the molecular weight is: 4 x 12.01 + 10 = 58.04. This is calculated for each carbon number.2. Divide the sum of the 2D GC data per carbon number by the molecular weight of the corresponding carbon number; this provides the mols of each detected molecule.3. Normalize the data from step 2. (i.e. : take the sum of step 2 and divide all data by that sum to get the mol. percentages %). This converts the measured mass % to mol %.4. For each carbon number, multiply the mol. % with the applicable carbon number.

[0036] The sum of step 4 is the average carbon number.

[0037] The boiling point of the renewable jet fuel component is preferably in the range from 130°C to 300°C, more preferably from 130°C to 295°C, even more preferably from 130°C to 290°C, , as measured according to ASTM D86.

[0038] The density of the renewable jet fuel component measured at 15°C, according toASTM D4052, is preferably in the range from 750 to 770 kg / m3, more preferably in the range from 760 to 770 kg / m3, even more preferably in the range from 765 to 770 kg / m3.

[0039] The renewable jet fuel / kerosene component of the present invention can be derived from any suitable source as long as it is suitable for use in an aviation fuel composition. In a preferred embodiment, the renewable jet fuel component is derived from renewable sources, more preferably those derived from the hydrotreating of vegetable oils (HVO) and / or HEFA (hydroprocessed esters and fatty acids).

[0040] Hydroprocessing involves various reactions where molecular hydrogen reacts with other components, or the component undergo molecular conversions in the presence of molecular hydrogen and a solid catalyst. Suitable hydroprocessing reactions include, but are not limited to, hydrogenation, hydrodeoxygenation, hydrodesulfurisation, hydrodenitrification, hydrometallization, hydrocracking, and hydroisomerisation.

[0041] In a preferred embodiment herein, the renewable jet fuel component is prepared by a process which comprises reacting a renewable feedstock in a hydrotreating zone in the presence of a hydrotreating catalyst to produce a hydrotreated effluent; reacting at least a portion of the hydrotreated effluent in a hydrocracking zone in the presence of a hydrocracking catalyst to produce a cracked effluent; reacting the cracked effluent in a hydroisomerization zone in the presence of a hydroisomerization catalyst to produce an isomerized effluent; separating the isomerized effluent to produce an offgas stream, at least one fuel stream having a kerosene boiling point range, and a heavy fraction having a boilingpoint greater than the kerosene boiling point range; and recycling at least a portion of the heavy fraction to the hydrocracking zone.

[0042] As used herein, the terms ‘renewable feedstock’, ‘renewable feed’ and ‘material from renewable sources’ means a feedstock from a renewable source. A renewable source may be animal, vegetable, microbial, and / or bio-derived or mineral-derived waste materials suitable for the production of fuels, fuel components and / or chemical feedstocks.

[0043] A preferred class of renewable materials are bio-renewable fats and oils comprising triglycerides, diglycerides, monoglycerides, free fatty acids, and / or fatty acid esters derived from bio-renewable fats and oils. Examples of fatty acid esters include, but are not limited to, fatty acid methyl esters and fatty acid ethyl esters. The bio-renewable fats and oils include both edible and non-edible fats and oils. Examples of bio-renewable fats and oils include, without limitation, algal oil, brown grease, canola oil, carinata oil, castor oil, coconut oil, colza oil, com oil, cottonseed oil, fish oil, hempseed oil, jatropha oil, lard, linseed oil, milk fats, mustard oil, olive oil, palm oil, peanut oil, rapeseed oil, sewage sludge, soy oils, soybean oil, sunflower oil, pongamia oil, tall oil, tall oil fatty acids (TOFA), tallow, used cooking oil, yellow grease, white grease, and combinations thereof.

[0044] Another preferred class of renewable materials are liquids derived from biomass and waste liquefaction processes. Examples of such liquefaction processes include, but are not limited to, (hydro)pyrolysis, hydrothermal liquefaction, plastics liquefaction, and combinations thereof. Renewable materials derived from biomass and waste liquefaction processes may be used alone or in combination with bio-renewable fats and oils.

[0045] Preferred feedstocks for use in the present invention were found to comprise C2 — C30 fatty acids, more preferably C8-C26 fatty acids, even more preferably C12-C24 fatty acids, or derivatives thereof such as anhydrides or esters of fatty acids as well as triglycerides and diglycerides of fatty acids, or combinations thereof.

[0046] While HEFA is the preferred renewable paraffinic-based kerosene / jet fuel component for use herein, the terms ‘renewable paraffinic kerosene’ and ‘renewable jet fuel component’ as used herein also includes kerosene derived from Fischer-Tropsch processes using biomass or biogas as feedstock, synthesized iso-paraffins from hydroprocessed fermented sugars, synthesized kerosene with aromatics derived by alkylation of light aromatics from non-petroleum sources, alcohol-to-jet synthetic paraffinic kerosene (ATJ- SPK), synthesized kerosene from hydrothermal conversion of fatty acid esters and fatty acids(HC-HEFA-SPK), alcohol-to-jet synthetic paraffinic kerosene with aromatics (ATJ-SKA), as defined in ASTM-7566.

[0047] The renewable materials to be used as feedstock in the process of the present invention may contain impurities. Examples of such impurities include, but are not limited to, solids, iron, chloride, phosphorus, alkali metals, alkaline-earth metals, polyethylene, and unsaponifiable compounds. If required, these impurities can be removed from the renewable feedstock before being introduced to the process of the present invention. Methods to remove these impurities are known to the person skilled in the art.

[0048] The process of the present invention is most particularly advantageous in the processing of feed streams comprising substantially 100% renewable feedstocks. However, in one embodiment of the present invention, renewable feedstock may be co-processed with petroleum-derived hydrocarbons. Petroleum-derived hydrocarbons include, without limitation, all fractions from petroleum crude oil, natural gas condensate, tar sands, shale oil, synthetic crude, and combinations thereof. The present invention is more particularly advantageous for a combined renewable and petroleum-derived feedstock comprising a renewable feed content in a range of from 30 to 99 wt.%. In one embodiment, the renewable feedstock is coprocessed with a heavy fraction from a petroleum refinery. For example, the petroleum-derived feedstock may be a heavy fraction from a gas oil unit.

[0049] Renewable feedstock is reacted in a hydrotreating zone to cause a hydrotreating reaction including, without limitation, hydrodeoxygenation, hydrodenitrogenation, hydrodesulphurization, hydrodearomatization, hydrogenation, hydrodemetallization, and combinations thereof. The reactions are preferably catalytic reactions, but may include non- catalytic reactions, such as thermal processing and the like. The hydrotreating zone may be a single-stage or multi-stage. In the case of catalytic reactions, the hydrotreating zone may be operated in a slurry, moving bed, fluidized bed, and / or fixed bed operation. In the case of a fixed bed operation, each reactor may have a single catalyst bed or multiple catalyst beds. The hydrotreating zone may be comprised of a single reactor or multiple reactors. The hydrotreating zone may be operated in a co-current flow, counter-current flow, or a combination thereof. Preferably, the hydrotreating zone is operated in a co-current flow.

[0050] The catalyst may be the same or different throughout the hydrotreating zone. The hydrotreating zone may comprise a single catalyst bed or multiple catalyst beds. The catalyst may be the same throughout the single catalyst bed, optionally there is a mixture of catalysts, or different catalysts may be provided in two or more layers in the catalyst bed. In anembodiment of multiple catalyst beds, the catalyst may be same or different for each catalyst bed.

[0051] In one embodiment, the hydrotreating zone further comprises a hydrogenation catalyst in advance of the hydrotreating catalyst. The hydrogenation components may be used in bulk metal form, or the metals may be supported on a carrier. Active metals for hydrogenation include catalytically active metals of Group VIII and / or Group VIB, including, without limitation, Ni, Co, Mo, W, and combinations thereof. Preferably, the hydrogenation catalyst comprises Mo. Suitable carriers include refractory oxides, molecular sieves, and combinations thereof. Examples of suitable refractory oxides include, without limitation, alumina, amorphous silica-alumina, titania, silica, and combinations thereof. Examples of suitable molecular sieves include, without limitation, zeolite Y, zeolite beta, ZSM-5, ZSM-12, ZSM-22, ZSM-23, ZSM-48, SAPO-11, SAPO-41, ferrierite, and combinations thereof.

[0052] The hydrotreating catalyst may be any catalyst known in the art that is suitable for hydrotreating. Catalyst metals are often in an oxide state when charged to a reactor and preferably activated by reducing or sulphiding the metal oxide. Preferably, the hydrotreating catalyst comprises catalytically active metals of Group VIII and / or Group VIB, including, without limitation, Pd, Pt, Ni, Co, Mo, W, and combinations thereof. Hydrotreating catalysts are generally more active in a sulphided form as compared to an oxide form of the catalyst. A sulphiding procedure is used to transform the catalyst from a calcined oxide state to an active sulphided state. Catalyst may be pre-sulphided or sulphided in situ. Because renewable feedstocks generally have alow sulphur content, a sulphiding agent is often added to the feed to maintain the catalyst in a sulphided form.

[0053] Preferably, the hydrotreating catalyst comprises sulphided catalytically active metals. Examples of suitable catalytically active metals include, without limitation, sulphided nickel, sulphided cobalt, sulphided molybdenum, sulphided tungsten, sulphided CoMo, sulphided NiMo, sulphided MoW, sulphided NiW, and combinations thereof. A catalyst bed / zone may have a mixture of two types of catalysts and / or successive beds / zones, including stacked beds, and may have the same or different catalysts and / or catalyst mixtures. In case of such sulphided hydrotreating catalyst, a sulphur source will typically be supplied to the catalyst to keep the catalyst in sulphided form during the hydroprocessing step.

[0054] The product of the hydrotreating reaction is optionally directed to a separation zone for separating the product of the hydrotreating reaction into a vapor phase effluent and a liquid hydrotreated effluent. Where the catalyst used for hydroisomerization has a noble metal, the separation zone is provided to remove or at least substantially reduce components that poison or otherwise adversely impact the hydroisomerization catalyst. Where a nonnoble metal is used for hydroisomerization, the separation zone is optional.

[0055] A portion of the hydrotreated effluent from one or more separator units may be returned to a hydrotreating zone, for example, as a quench stream or as a diluent of feedstock. The volumetric ratio of diluent to fresh renewable feedstock is preferably in a range of from 1 : 1 to 30: 1. The quench stream is used to control temperature in the hydrotreating zone and therefore typically cooled using, for example, an air cooler or a heat exchanger. One or more quench streams may be added between catalyst beds / zones in the hydrotreating zone.

[0056] The hydrotreated effluent (with or without a separation step) is passed to a hydrocracking zone in the presence of a hydrocracking catalyst to produce a hydrocracked effluent. The hydrotreated effluent is primarily comprised on n-paraffms. Some iso-paraffins may be present in an amount of less than 5 wt.%. The pour point of the hydrotreated effluent is in a range for from 20 to 25°C.

[0057] The hydrocracking catalyst may be any suitable catalyst composition known to those skilled in the art. Preferably, the hydrocracking catalyst comprises a Group VIII metal. More preferably, the hydrocracking catalyst further comprises an acidic material.

[0058] The acidic material may be an amorphous acidic material, a crystalline acidic material, or a combination thereof. The amorphous acidic material may be, for example, without limitation, amorphous silica alumina. The crystalline acidic material may be selected from the group consisting of Beta, Faujasite, Mordenite, COK-7, EU-1, EU-2, EU-11, IZM- 1, MCM-22, NU-10, ZSM-5, ZSM-12, ZSM-22, ZSM-23, ZSM-30, ZSM-35, ZSM-48, ZSM-50, ZSM-57, and combinations thereof.

[0059] Preferably, the Group VIII metal is selected from the group consisting of platinum, palladium, nickel, and combinations thereof. When the Group VIII metal is Ni, the hydroisomerization catalyst preferably includes a Group VI metal, preferably Mo or W.

[0060] The hydrocracking catalyst may further comprise a binder and / or carrier, such as, without limitation, silica, alumina, silica-alumina, and combinations thereof.

[0061] The hydrocracking zone is operated in the presence of hydrogen at a pressure in a range of from 1 MPa to 30 MPa and at a temperature in a range of from 260°C to 400°C.Preferably, the pressure is in a range of from 2 MPa to 18 MPa, and the temperature is in a range of from 280°C to 400°C.

[0062] The hydrocracking conditions and catalyst are selected to favour cracking over branching.

[0063] The hydrocracking zone may be provided in a stacked-bed configuration above a hydroisomerization zone. In this embodiment, the hydrotreated effluent and a recycled heavy fraction are passed to a single stage reactor comprising both the hydrocracking zone and the hydroisomerization zone. The hydrocracked effluent from the hydrocracking zone is then passed to the hydroisomerization zone for isomerizing the hydrocracked effluent.

[0064] In another embodiment, the hydrocracking zone and the hydroisomerization zone are provided in a two-stage configuration. In this embodiment, the hydrotreated effluent and the recycled heavy fraction are passed to the hydrocracking zone. The hydrocracked effluent from the hydrocracking zone is then passed to the hydroisomerization zone for isomerizing the hydrocracked effluent.

[0065] The hydrocracked effluent is passed to the hydroisomerization zone in the presence of a hydroisomerization catalyst to produce an isomerized effluent reaction. The hydroisomerization reaction increases branching of the paraffinic compounds resulting from the hydrotreating zone, thereby improving the cold flow properties of the fuel.

[0066] The hydroisomerization catalyst may be any suitable catalyst composition known to those skilled in the art. Preferably, the hydroisomerization catalyst comprises a Group VIII metal. More preferably, the hydroisomerization catalyst further comprises a zeolitic material. The hydroisomerization catalyst may further comprise a binder and / or carrier, such as, without limitation, silica, alumina, titania, silica-alumina, and combinations thereof. Preferably, the Group VIII metal is selected from the group consisting of platinum, palladium, nickel, and combinations thereof. When the Group VIII metal is Ni, the hydroisomerization preferably includes a Group VI metal, preferably Mo or W.

[0067] The zeolitic material is preferably selected from the group consisting of Beta, COK-7, EU-1, EU-2, EU-11, IZM-1, MCM-22, NU-10, ZSM-5, ZSM-12, ZSM-22, ZSM- 23, ZSM-30, ZSM-35, ZSM-48, ZSM-50, ZSM-57, and combinations thereof.

[0068] The catalyst may be the same or different throughout the hydroisomerization zone. The hydroisomerization zone may comprise a single catalyst bed or multiple catalyst beds. The catalyst may be the same throughout the single catalyst bed, optionally there is a mixture of catalysts, or different catalysts may be provided in two or more layers in thecatalyst bed. In an embodiment of multiple catalyst beds, the catalyst may be same or different for each catalyst bed.

[0069] The hydroisomerization zone may optionally include a hydrofinishing zone. During the hydroisomerization step and / or depending on the feedstock used, some aromatics and / or trace olefins may be present in the effluent of the hydroisomerization zone. In this case, the hydrofinishing step is preferably provided to reduce the aromatic content of the product stream(s).

[0070] The hydrofinishing components may be used in bulk metal form, or the metals may be supported on a carrier. Active metals for hydrogenation include catalytically active metals of Group VIII and / or Group VIB, including, without limitation, Ni, Co, Mo, W, and combinations thereof. Preferably, the Group VIII metal is selected from the group consisting of platinum, palladium, nickel, and combinations thereof. Suitable carriers include refractory oxides. Examples of suitable refractory oxides include, without limitation, alumina, amorphous silica-alumina, titania, silica, and combinations thereof.

[0071] The hydroisomerization zone is operated in the presence of hydrogen at a pressure in a range of from 1 MPa to 30 MPa and at a temperature in a range of from 260°C to 400°C. Preferably, the pressure is in a range of from 2 MPa to 17 MPa, and the temperature is in a range of from 300°C to 380°C. The ratio of the hydrogen gas to the combined liquid supplied to the hydroisomerization zone is in a range of from 100 to 1500 normal L (at standard conditions of 0 °C and 1 atm (0. 1 MPa)) per kg of the hydrotreated effluent.

[0072] Hydroisomerization is particularly advantageous for improving the production of kerosene for jet fuel. The hydroisomerization conditions and catalyst are selected to favour branching over cracking.

[0073] The product from the hydroisomerization zone is directed to a work-up section. Various embodiments for the work-up section may be considered. For example, without limitation, the work-up section may be as described in WO2023 / 043792 or WO2023 / 043764 published 2023 March 23, incorporated by reference herein.

[0074] The work-up section includes one or more product recovery zones resulting in desired product streams. Desired product streams include, for example, an off-gas stream, optionally a naphtha boiling point range stream, a kerosene boiling point range stream, optionally a diesel boiling point range stream, and a heavy fraction. The off-gas stream suitably comprises C1-C5 hydrocarbons, while the naphtha boiling point range suitably comprises C4-C12 hydrocarbons in a boiling point range of from -12°C to 204°C. Thekerosene boiling point range stream is preferably comprised of C6-C22 hydrocarbons, comprising hydrocarbons which have a variety of individual boiling points in the range of 60°C to 380°C, which overall results in a kerosene fraction having a boiling point preferably in the range of 120-300°C. In one embodiment, the diesel boiling point range stream comprises C8-C26 hydrocarbons having a boiling point range of from 120°C to 400°C. In this embodiment, the heavy fraction has C17+ hydrocarbons having a boiling point greater than 250°C. Distillation temperatures of 300°C or more were found to be incapable of resulting in a kerosene fraction with a freezing point of -60°C or below.

[0075] The process of the present invention is directed towards improving the yield of the kerosene boiling point range stream. In a preferred embodiment, the process is directed toward a kerosene product meeting the specifications of ASTM D7566, wherein a synthesized paraffinic kerosene from HEFA has a T10 distillation temperature (using ASTM Test Method D86) maximum of 205°C and a final boiling maximum of 300°C.

[0076] Where a diesel boiling point range stream is produced in the work-up section, at least a portion of the diesel boiling point range stream is recycled with the heavy fraction. Another portion of the diesel boiling point range stream may be drawn off as a bleed stream. The product recovery zone may include a further separation of the diesel boiling point range stream into a light diesel stream that may be drawn off as a bleed stream, for example, while the heavy diesel stream is recycled with the heavy fraction.

[0077] Where a separate product stream of diesel boiling point range hydrocarbons is not produced in the work-up section, the diesel boiling point range hydrocarbons part of the heavy fraction and are recycled for cracking and isomerization to extinction.

[0078] In the process of the present invention, the amount of recycle for the heavy fraction can be selected such that a combined feed ratio (CFR) is in a range of from 1 to 2, on a weight basis, according to the following formula:CFR = HF + RF) / HF where HF is the hydrotreated effluent (with or without a separation step) that is passed to the hydrocracking zone, while RF is the portion of the heavy fraction that is recycled to the hydrocracking zone. The recycle fraction has an iso-paraffin content of at least 95 wt.%, preferably at least 98 wt.%, more preferably at least 99 wt.%, most preferably substantially 100 wt.%.

[0079] The renewable jet fuel component can be incorporated into ajet fuel composition either as sole blending component or can be blending with other types of jet fuel components such as petroleum-derived jet fuel components, Fischer-Tropsch derived jet fuel components, and other synthetically-derived jet fuel components, and mixtures thereof.

[0080] Preferably, the renewable jet fuel component is present in the jet fuel composition in an amount from 1 wt.% to 99 wt.%, more preferably from 5 wt.% to 95 wt.%, even more preferably from 10 wt.% to 80 wt.%, and especially from 50 wt.% to 80 wt.%, based on the jet fuel composition.

[0081] It has been found that when the renewable jet fuel component is used in ajet fuel composition comprising a renewable jet fuel component and a variety of petroleum-derived kerosene components available on the market at a level of 1% or greater, preferably 5% or greater, even more preferably 10% or greater, by volume of the total jet fuel composition, the freezing point of the final jet fuel composition is reduced as compared to the petroleum- derived kerosene component alone, where the petroleum-derived kerosene component has a freezing point of -60°C or greater (for clarity, greater meaning -59°C, -58°C and so on).

[0082] Preferably, the jet fuel composition comprises a petroleum-derived kerosene in addition to the renewable jet fuel component.

[0083] A petroleum-derived kerosene base fuel or kerosene range hydrocarbon component for use herein is any petroleum-derived kerosene that may be useful as ajet fuel, or ajet fuel blending component having a boiling point in the range from 130°C to 300°C, at atmospheric pressure (as measured by ASTM D86), preferably in the range from 140°C to 300°C, and most preferably in the range from 145°C to 300°C. For ajet fuel blending component, the kerosene base fuel (whether single stream or a mixture) can have a flashpoint of 38°C or above (measured by ASTM D56), and a density at 15°C of at least 775 kg / m3(as measured by ASTM D4052). The petroleum-derived kerosene base fuel may be any petroleum-derived jet fuels known to those skilled in the art, including kerosene fuels meeting at least one of Jet A, Jet A-l, F-24, JP-8, F-44, JP-5, Jet B or AN-8 specifications.

[0084] Preferably, the petroleum-derived kerosene base fuel is a kerosene that can meet the prevailing jet fuel specification properties. For example, petroleum-derived kerosene fuels meeting Jet A or Jet A-l requirements and a kerosene stream used in Jet A or Jet A-l production are: a straight run kerosene stream, a caustic washed or straight run kerosene, a kerosene stream further purified via a sweetening process such as Merox (RTM), Merichem (RTM), or Bender process, or a hydroprocessed jet fuel. It is also contemplated thatpetroleum-derived kerosene fuels which do not meet Jet A or Jet A-l specifications may be used as petroleum-derived kerosene base fuels that can be upgraded to meet such specifications by blending with the renewable jet fuel component of the present invention.

[0085] As another example, the low boiling fraction as separated from a mineral gas oil may be used as such or in combination with a petroleum-derived kerosene, suitably made at the same production location. As the low boiling fraction may already comply with a jet fuel specification, the blending ratio between said component and the petroleum-derived kerosene may be freely chosen. The petroleum-derived kerosene will typically boil for more than 90 vol% within the usual kerosene range of 145°C to 300°C (ASTM D86), depending on grade and use. It will typically have an initial boiling point in the range from 130°C to 190°C, and a final boiling point in the range 220°C to 300°C. It will typically have a density from 775 to 840 kg / m3at 15°C (e.g. ASTM D4052 or IP365). Its kinematic viscosity at -20°C (ASTM D445) may suitably be up to a maximum of 8.0 mm2 / s. The petroleum- derived kerosene base fuel or kerosene range hydrocarbon component may be a straight run kerosene fraction as isolated by distillation from a crude oil source or a kerosene fraction isolated from the effluent of typical refinery conversion processes, preferably hydrocracking. The kerosene fraction may also be the blend of straight run kerosene and kerosene as obtained in a hydrocracking process. Suitably, the properties of the mineral derived kerosene are those of the desired jet fuel.

[0086] The aromatic content of the petroleum-derived kerosene base fuel may vary in the range from 0 to 25 vol%, preferably 3 to 25 vol%, more preferably from 15 to 20 vol%, based on the total petroleum-derived kerosene base fuel (as measured by ASTM 1319). The petroleum-derived kerosene base fuel most useful herein may have a density at 15°C of at least 775 kg / m3, to preferably at most 840 kg / m3, and more preferably at most 820 kg / m3.

[0087] The petroleum-derived kerosene base fuel may be a single stream from a refining stream or a mixture of one or more refining streams, or a mixture of refining streams and one or more synthetic kerosene components, or one of more synthetic kerosene streams approved by ASTM D7566 or equivalent specifications.

[0088] In one embodiment, the petroleum-derived kerosene has a freeze point of more than -60°C (e.g. -59°C). A preferred petroleum-derived kerosene is Jet-A petroleum-derived kerosene.

[0089] It has been found that by blending the renewable jet fuel component with a petroleum-derived kerosene, the resulting blend has a reduced freeze point compared to thatof the petroleum-derived kerosene alone. Hence, according to the present invention there is a further provided use of a renewable jet fuel component as described herein for improving (reducing) the freeze point of a petroleum-derived kerosene.

[0090] According to the present invention, there is further provided a method of improving (reducing) the freeze point of a petroleum-derived kerosene, the method comprising blending an amount of the renewable jet fuel component described herein with an amount of a petroleum-derived kerosene to produce a jet fuel composition, wherein the amount of the jet fuel component is preferably greater than 1% by volume of the jet fuel composition. The resulting jet fuel composition has a reduced freeze point as compared to the petroleum-derived kerosene alone.

[0091] In one embodiment of the present invention, the renewable jet fuel component described herein is capable of lowering the freeze point of Jet- A petroleum derived kerosene to meet Jet-Al freeze point requirements as set out in ASTM D1655. Further, the renewable jet fuel component is capable of bringing a Jet-A petroleum-derived kerosene within the requirements of the Jet-Al petroleum-derived kerosene specification ASTM D1655, particularly in terms of freeze point requirements. In such embodiment, an amount of 15% by volume or more of the renewable jet fuel component, by volume of the final blend, should be blended with a Jet-A petroleum derived kerosene.

[0092] In a further embodiment, the renewable jet fuel component described herein is capable of lowering the freeze point of Jet-A petroleum derived kerosene to meet Jet-B freeze point requirements as set out in ASTM D6615. Further, the renewable jet fuel component is capable of bringing a Jet-A petroleum-derived kerosene within the requirements of the Jet-B petroleum-derived kerosene specification ASTM D6615, particularly in terms of freeze point and density requirements. In such embodiment, an amount of 30 vol% or more of the renewable jet fuel component, by volume of the final blend, should be blended with a Jet-A petroleum derived kerosene.

[0093] In a further embodiment, the renewable jet fuel component described herein is capable, either alone or in a blend with a petroleum-derived kerosene, of meeting the requirements of JP-8 and JP-8 variant standards as specified in British Defence Standard 91- 87 and MIL-DTL-83133.EXAMPLES

[0094] The following non-limiting examples of embodiments of the method of the present invention as claimed herein are provided for illustrative purposes only.Example 1

[0095] A stacked catalyst bed consisting of 60 mL of a hydrocracking catalyst (0.8 wt.% Pt on an amorphous silica-alumina support) stacked above 60 mL of a hydroisomerisation catalyst (0.7 wt.% Pt on a carrier comprising 75 wt.% silica and 25 wt.% zeolite ZSM-12) was placed in a reactor. The catalyst was 1:1 diluted with 0,2 mm diameter silicon carbide particles. The silicon carbide particles were applied to mitigate reactor wall effects which could disturb the uniform liquid distribution over the catalyst bed cross section.

[0096] The temperature of the bed was controlled by means of an oven. The stacked catalyst bed was operated at a WABT of 346°C. A hydrodeoxygenated soybean oil was supplied to the top of the stacked catalyst bed at a WHSV (weight hourly space velocity) of 1.0 g fresh liquid per mL catalyst per hour. A gas stream comprising 100% vol% hydrogen was supplied to the top bed at a gas-to-oil ratio of 500 NL / kg. The total pressure at the reactor outlet was 73 barg (7.3 MPag). The reactor effluent was routed to a high-pressure gas / liquid separator (HPS). The liquid was sent to an atmospheric distillation column. The column was operated at an effective cut point of about 290°C, as determined from the D2887 data measured on the top and bottom as mentioned below. The bottom fraction of the column was recycled to the top of the stacked catalyst bed. The combined feed ratio was 1.7 on a weight basis. The produced gasses, retrieved from the HPS and distillation column were analysed by on-line gas chromatography. The total liquid product retrieved from the top of the column, and aliquots withdrawn from the bottom (recycle), were analysed by ASTM D2887. Freeze point of the total liquid product was measured using ASTM D5972. The yields of the various boiling fractions and the freeze point of the recovered total liquid product are presented in Table 1.Comparative Example 2

[0097] The process illustrated in Fig. 1 of van Doesburg et al. (W02024 / 006886A1, 2024-01-04) was tested to demonstrate the benefits of the present invention with respect to yield and freeze point.

[0098] A stacked catalyst bed consisting of 60 mL of a hydrocracking catalyst (0.8 wt.% Pt on an amorphous silica-alumina support) stacked above 120 mL of a hydroisomerisation catalyst (0.7 wt.% Pt on a carrier comprising 75 wt.% silica and 25 wt.% zeolite ZSM-12) was placed in a reactor. The catalyst was 1.1 diluted with 0.2 mm diameter silicon carbide particles. The silicon carbide particles were applied to mitigate reactor wall effects which could disturb the uniform liquid distribution over the catalyst bed cross section.

[0099] The temperature of the bed was controlled by means of an oven. The stacked catalyst bed was operated at a WABT of 344°C. A hydrodeoxygenated soybean oil was supplied to the HIS catalyst bed at a WHSV of 1.0 g fresh liquid per mL catalyst per hour. A gas stream comprising 100% vol% hydrogen was supplied to the top bed at a gas-to-oil ratio of 500 NL / kg. The total pressure at the reactor outlet was 73 barg (7.3 MPag). The reactor effluent was routed to a high-pressure gas / liquid separator (HPS). The liquid was sent to an atmospheric distillation column. The column was operated at an effective cut point of about 290°C, as determined from the D2887 data measured on the top and bottom as mentioned below. The bottom fraction of the column was recycled to the HC catalyst bed. The combined feed ratio was 1.7 on a weight basis. The produced gasses, retrieved from the HPS and distillation column were analysed by on-line gas chromatography. The total liquid product retrieved from the top of the column, and aliquots withdrawn from the bottom (recycle), were analysed by ASTM D2887. Freeze point of the total liquid product was measured using ASTM D5972. The yields of the various boiling fractions and the freeze point of the recovered total liquid product are presented in Table 1.TABLE 1

[0100] Surprisingly, the results show that the yield of kerosene boiling point range was significantly increased, whilst the yield of lighter components was reduced, by the process of the present invention. By hydrocracking the hydrotreated soybean oil before hydroisomerization, it was expected that the yield of lower boiling components would be increased. Furthermore, it was surprising that the freeze point of the kerosene fraction was significantly reduced.Example 3

[0101] Both the produced total liquid product samples from Example 1 and Comparative Example 2 were distilled, off-line, at an effective cut point of about 120°C. The recovered kerosene fractions were analysed on density (ASTM D4052), freeze point (ASTM D5972), flash point (ASTM D93), and boiling curve (ASTM D86). In addition, information on the molecular composition was obtained by two-dimensional gas chromatography. Results can be found in Tables 2 - 4, where values are shown to two decimal places for given weight percentages.TABLE 2TABLE 3TABLE 4

[0102] Example 3 shows that the renewable jet fuel component of the invention has a significantly reduced freezing point, where the most influential factors to reduce freezing point were found to be an increased total iso-paraffin to normal paraffin weight-based ratio, an increased total iso-paraffins with more than 2 branches to total mono-branched iso-paraffins weight-based ratio and a lower amount of Cl 5, Cl 6 and Cl 7 n-paraffins in respect to total C15, C16 and C17 paraffins.Example 4

[0103] In order to estimate the necessary volumes required to improve the freezing point in a jet fuel blend comprising the renewable jet fuel component of the invention and a petroleum-derived jet fuel, two commercially available Jet A samples (acquired from the Martinez Refinery and Norco Refinery) and two commercially available Jet Al samples (acquired from the Scotford Refinery and Sarnia Refinery) were used in a calculated blending exercise using simple liner relation. For example, in order to estimate the freezing point of a blend comprising 50% of the renewable jet fuel component of the invention and 50% of the petroleum derived kerosene, where the respective freezing points are -69 °C and -43.2°C the calculation would be as follows: [(0.5 x (-69) + (0.5 x (-43.2)) = -56.1°C]. Properties for the Jet A and Jet Al samples are provided in Table 5. Results of the calculated blending exercise are shown in Tables 6 - 9.TABLE 5TABLE 6TABLE 7TABLE 8TABLE 9

[0104] The low freezing point of the renewable jet fuel component of the invention is capable of reducing the freezing-point of a Jet-A blend at all volumes measured and is capable of modifying a kerosene meeting Jet A freezing-point specification (Max -40 °C) to meet Jet A-l specifications (Max -47 °C) when the renewable composite is present at 15% or more in the blend. Further blends were made using another petroleum derived Jet A kerosene (Jet A Sample 2), and two further blends with petroleum-derived Jet-Al kerosene fuels (Jet A-l Sample 1 and Jet A-l Sample 2). In all cases, the addition of the renewable composite at 1 %vol or more in the blend was capable of reducing the freezing-point of the jet fuel blend, as compared to the freezing point of the petroleum derived jet fuel alone.

Claims

CLAIMS1. A renewable j et fuel component comprising: a total iso-paraffin content of up to 90 wt.%, a C7-C14 paraffins content of at least 40 wt.%, a C15-C18 paraffins content of at most 60 wt.%, a C17-C18 paraffins content of at most 40 wt.%, a Cl 8 paraffins content in a range of from 2 to 10 wt.%, a >C18 paraffins content of at most 1 wt.%, wherein the iso-paraffin branching is such that a weight ratio of the sum of wt.% amounts of paraffins with more than 2 branches, to a sum of wt.% amounts mono-branched paraffins, is in a range from 1 to 2, wherein the ratio of total isoparaffins to n-paraffins is more than 11.2, and wherein the renewable jet component has a freezing point of less than -60°C, a flashpoint of 40°C or more and a density of 770 kg / m3or less.

2. The renewable jet fuel component of claim 1, wherein no more than 10, 4.8 or 0.1 wt.% of the C15, C16 and C17 paraffins respectively, when considered individually, are n-paraffins.

3. The renewable jet fuel component of claim 1 or claim 2, wherein the ratio of total iso-paraffins wt.% to total n-paraffins wt.% in renewable jet fuel component is 11.2 or greater.

4. The renewable jet fuel component of any of claims 1 to 3, wherein the C9, CIO, C11, C12, C13 paraffins, when considered independently as sub-groups, each make up at least 5 wt.% of the total jet fuel component, and wherein the factor of increase of the smallest wt.% of these sub-groups as compared to the largest wt.% is from 1 to 2.2.

5. A renewable jet fuel component according to any of claim 1 to 4, wherein the renewable jet fuel component has a density at 15°C in the range from 750 to 770 kg / m3.

6. A process for preparing the renewable jet fuel component of any of claims 1 to 5, comprising the steps of (i) reacting a renewable feedstock in a hydrotreating zone in the presence of a hydrotreating catalyst to produce a hydrotreated effluent, (ii) reacting at least a portion of the hydrotreated effluent in a hydrocracking zone inthe presence of a hydrocracking catalyst to produce a cracked effluent, (iii) reacting the cracked effluent in a hydroisomerization zone in the presence of a hydroisomerization catalyst to produce an isomerized effluent; (iv) separating the isomerized effluent to produce an offgas stream, at least one fuel stream having a kerosene boiling point range, to produce a renewable jet fuel component, and a heavy fraction having a boiling point greater than the kerosene boiling point range; and (v) recycling at least a portion of the heavy fraction to the hydrocracking zone.

7. A jet fuel composition comprising the renewable jet fuel component of any of claim 1 to 5.

8. A jet fuel composition according to claim 7, additionally comprising a petroleum derived kerosene having a freeze point of greater than -60°C.

9. Use of the renewable jet fuel component of any of claims 1 to 5 for reducing the freeze point of a petroleum-derived kerosene.

10. A method for reducing the freeze point of a petroleum-derived kerosene by blending of at least 1% the renewable jet fuel component of any of claims 1 to 5 with a petroleum-derived kerosene having a freeze point of greater than -60°C.

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