Technical Field

The present invention relates to processes for preparing hydrocarbons from an oxygenated hydrocarbon feedstock having nitrogen impurities, and in particular to an efficient utilisation of hydrogen in such processes.

Background Art

Converting fossil oils (such as crude oils) and renewable oils (such as plant oils or animal fats) into valuable products, such as transportation fuels (e.g. gasoline, aviation fuel and diesel) involve hydrotreating processes, which consumes hydrogen.

Refining of heavy crude oil and low quality plant oils and animal fats, such as waste animal, fat increases the hydrogen demand in hydrotreating processes. Thus, generating, recovering and purchasing of hydrogen for hydrotreatment of oil have significant impact on refinery operating costs.

Hydrotreating of fossil and renewable oils are performed with an excess of hydrogen compared to the theoretical consumption. The hydrogen remaining after hydrotreating step may be purified and recycled together with additional fresh hydrogen to make up for the hydrogen consumed in the hydrotreating step, the so-called make-up hydrogen.

During hydrotreating a number of reactions occur to various extents depending on the feedstock composition. Hydrotreating reactions include double bond hydrogenation, hydrodeoxygenation (HDO), hydrodesulfurisation (HDS), hydrodenitrification (HDN), hydrodearomatisation (HDAr), hydrocracking (HC) and hydroisomerisation.

Hydroisomerisation is typically done on a bifunctional catalyst having both metal dehydrogenation function and acidic function, for example platinum or palladium catalysts together with molecular sieves such as SAPO-11 . Isomerisation selectivity of the catalyst is important, i.e. typically hydrocracking that also occurs to a certain extent during hydroisomerisation is suppressed, if during hydrotreatment it is not desired to reduce the average molecular weight of feed. This involves a balance between metal dehydrogenation function and acidic functions, which is sensitive to elements that can shift this balance. It is speculated that amines neutralise strong acid sites, leading to low catalyst acidity and activity. Sulfur is known to poison the metal dehydrogenation function of noble metal catalysts.

One of the common feed impurities include nitrogen, which are well-known constituents of oil of fossil and of renewable origin, as well as animal waste fat. In crude oil average nitrogen impurity contents of 940 w-ppm and contents as high as 7500 w-ppm has been reported (Manrique et al. (1997) Basic Nitrogen Compounds in Crude Oils: Effect on Mineral Dissolution During Acid Stimulation Processes, SPE-37224-MS; https://www.onepetro.org/conference-paper/SPE-37224-MS). It is also not uncommon that animal waste fat can contain 1000 ppm nitrogen or even higher. The typical way of handling undesirable impurities in feedstocks, such as nitrogen impurities, is to purify the feedstock prior to hydrotreatment. It is typical to remove the water-soluble nitrogen compounds through degumming. However, in animal fat, a major part of the nitrogen compounds are oil soluble, and much more difficult to remove than the water-soluble nitrogen compounds.

US 2011/0094149 A1 (to IFP Energies Nouvelles) describes methods of hydrotreating feeds from renewable sources in two catalytic zones using a molybdenum catalyst, where the gaseous and liquid effluent from the beds having a higher temperature at the outlet than at the inlet, due to the exothermic nature of the hydrotreatment reaction, is used directly as recycle to heat fresh feed to the catalytic zones. US 2011/0094149 A1 exemplifies the invention using good quality palm oil and soy oil having a small nitrogen impurity of 15 and 23 ppm, respectively, and mentions that feeds from renewable sources generally contain various impurities, such as a nitrogen impurity of generally 1-100 ppm, and even up to 1 wt%. US 2011/0094149 A1 reduces the nitrogen amount in the examples to about 2% of the original amount and does not hydrotreat any impure feed having a nitrogen content outside the general range of 1 -100 ppm. Comparative example 1 hydrotreats and isomerises animal fat having a nitrogen content of about 1 wt% at process conditions described in US 2011/0094149 A1 , showing that it is possible to hydrotreat impure feeds having a nitrogen content outside the general range of 1- 100 ppm. However, the nitrogen content after the hydrodeoxygenation stages is about 2-5 ppm, and after isomerisation, the yield of aviation fuel cut was only 5% having a high pour point of -10°C compared to the requirements for aviation fuels.

Consequently, there is a need for further hydrotreatment processes that can effectively hydrotreat oxygenated hydrocarbons having a nitrogen impurity outside the general range of 1 -100 ppm and ensure a low nitrogen amount in the hydrotreated product. Additionally, there is a need for processes that can produce a high quality aviation fuel cut having good cold flow properties from oxygenated hydrocarbons having a nitrogen impurity outside the general range of 1-100 ppm.

There is a possibility of purifying the feed further before hydrogenation to remove as much nitrogen as possible. However, while purification methods to remove water soluble nitrogen are easily implemented, a lot of the nitrogen content in animal fat is oil soluble, and much more difficult to remove.

Additionally, there is a need for more efficient use of hydrogen, which is added in excess and usually recycled.

Summary of the Invention

The present invention was made in view of the prior art described above, and the object of the present invention is to provide a process that can improve the quality of a hydrotreated product obtained from an oxygenated hydrocarbon feed containing nitrogen impurities, while at the same time making more efficient use of the hydrogen. In particular the improved quality at least includes a low amount of nitrogen impurity in the product, as well as improved cold flow properties of the isomerised product.

To solve the problem, the present invention provides a process for preparing hydrocarbons from an oxygenated hydrocarbon feedstock having a nitrogen impurity of 10 wppm or more, measured as elemental nitrogen, where the process comprises a reactor (101) comprising a first catalytic zone/polishing zone (102) arranged upstream of a second catalytic zone/hydrotreatment zone (105). The oxygenated hydrocarbon feedstock is fed to the hydrotreatment zone and the effluent from the first hydrotreating zone is purified, and where the purified effluent from the first hydrotreating zone (108) is hydrotreated at a higher temperature in the polishing zone (102) and where the feed to the polishing zone (102) is not mixed with an oxygenated hydrocarbon feedstock, i.e. is not mixed with fresh feed.

Specifically, the invention relates to a process for preparing hydrocarbons from an oxygenated hydrocarbon feedstock having a nitrogen impurity of 10 wppm or more, measured as elemental nitrogen, comprising:

- a hydrotreatment reactor (101) comprising a first catalytic zone (102) arranged above a second catalytic zone (105), in which a hydrotreatment entry stream comprising the oxygenated hydrocarbon feedstock (104), a hydrogen-rich gas (120), and optionally a product recycle diluting agent (108, 126), is introduced to the second catalytic zone (105) at an inlet between the first (102) and the second catalytic zone (105), where it is mixed with part of a first hydrotreated effluent from the first catalytic zone, where the second catalytic zone is operated at a temperature and a pressure causing at least hydrodeoxygenation and hydrodenitrification to an extent where a second hydrotreated effluent (106) from the second catalytic zone (105) of the hydrotreatment reactor contains mainly hydrocarbons, and wherein the oxygenated hydrocarbon feedstock has been converted to >95% hydrocarbons;

- the second hydrotreated effluent from the second catalytic zone of the hydrotreatment reactor is subjected to a separation stage (107) where at least part of the second hydrotreated effluent (106) is separated into a gaseous fraction (121) and a hydrotreated liquid (108), where the hydrotreated liquid contains >95 wt% hydrocarbons and >1 wppm nitrogen;

- at least part of the hydrotreated liquid (108) and a hydrogen-rich gas (120) is introduced into the hydrotreatment reactor (101) to the first catalytic zone (102), at an inlet temperature that is higher than the inlet temperature in the second catalyst zone of the hydrotreatment reactor and at a pressure causing hydrodeoxygenation and hydrodenitrification;

- a product side stream (112) containing part of the first hydrotreated effluent from the first catalytic zone (102) is taken out between the first and second catalytic zones, the product side stream (112) containing a liquid component and a gaseous component, and where the liquid component of the side stream contains >99 wt% hydrocarbons and <1 wppm nitrogen, preferably <0.4 wppm nitrogen, such as <0.3 wppm nitrogen (the ASTM D4629 detection), measured as elemental nitrogen;

That is, the inventors of the present invention in a first aspect of the invention found that oxygenated hydrocarbons containing a nitrogen impurity amount can be effectively hydrotreated in two catalytic zones within a reactor, when ammonia and other low boiling amines are removed from the effluent from the second catalytic zone (105) (hydrotreating zone) by separation into a gaseous and a liquid phase, followed by hydrotreating the liquid phase therefrom in a first catalytic zone (102) (polishing zone), in which this liquid phase is neither combined with other oxygenated hydrocarbon feeds, nor combined with other feeds having a higher nitrogen content than the first hydrotreated liquid. At least part of the first hydrotreated effluent is taken out as a side stream and separated into a gaseous stream and a second hydrotreated liquid stream, which separation may be a stripping step or be followed by a stripping step (114), where the first hydrotreated liquid stream may be stripped with a stripping gas, such as hydrogen to lower the nitrogen content of the stripped side stream (115) to 0.3 wppm or lower.

Specifically, the inventors have found that ammonia present in the hydrogen-rich effluent gas, which has been formed from the nitrogen impurities of the feed during hydrotreating, can be reincorporated into the product during deeper hydrodeoxygenation/hydrodenitrification conditions, if hydrogen-rich gas containing such ammonia impurities is used in a polishing step without prior removal of the ammonia impurity.

By using a polishing zone (first catalytic zone) upstream of a hydrotreating zone (second catalytic zone) fresh hydrogen can be better utilised compared to a reactor with a polishing zone downstream of a hydrotreating zone. This is because the feed to the first catalytic zone (102) (polishing zone) already contains lower amounts of nitrogen compared to the oxygenated hydrocarbon feed to the second catalytic zone (105) (hydrotreating zone), and the fresh hydrogen added to the polishing zone will not contain the nitrogen impurities that are present in the effluent from the second catalytic zone, and at the same time, the excess hydrogen present in the effluent from the first catalytic zone (102) (polishing zone) remains of a suitable quality for use in the second catalytic zone (105) (hydrotreating zone).

The reactor setup and process of the present invention causes a more efficient hydrogen usage while at the same time ensuring low amounts of nitrogen impurities of the product product side stream (112).

The product product side stream (112) may be used as a product of its own or it may also be isomerised in an isomerisation reactor (103) comprising at least one catalytic zone, in which the product product side stream (112) and a hydrogen-rich gas (120), which hydrogen-rich gas may contain <1 ppm (mol/mol) nitrogen, measured as elemental nitrogen, is introduced into the catalytic zone at an inlet temperature and a pressure causing at least hydroisomerisation to produce an isomerised effluent (116);

- the isomerised effluent from the isomerisation reactor is subjected to a separation stage (117), where the isomerised effluent (116) is separated into a gaseous fraction (118) and an isomerised liquid (119), where the isomerised liquid contains >30 wt% branched hydrocarbons, and/or an increase in branched hydrocarbons of >30 wt% compared to the product product side stream (112).

For example, the side stream may be subjected to a stripping stage (114), where the side stream (116) is stripped with a stripping gas (H2) causing the stripped side stream (115) to have <0.4 wppm nitrogen, such as <0.3 wppm nitrogen (the ASTM D4629 detection), measured as elemental nitrogen, and a lower nitrogen amount compared to the side stream (116); may be subjected to a step of isomerising this stripped side stream (115) in an isomerisation reactor (103) comprising at least one catalytic zone, in which the stripped side stream (115) and a hydrogen-rich gas (120) having <1 ppm (mol/mol) nitrogen, measured as elemental nitrogen, is introduced into the catalytic zone at a temperature and a pressure causing at least hydroisomerisation to produce a first isomerisation effluent (116); where the isomerised effluent from the isomerisation reactor (103) is subjected to a separation stage, where the isomerised effluent is separated into a gaseous fraction and an isomerised liquid, where the first isomerised liquid contains >30 wt% branched hydrocarbons, and/or an increase in branched hydrocarbons of >30 wt% compared to the stripped side stream (115).

The isomerised liquid may be separated into at least an aviation fuel having a freeze point of -40 °C or lower, such as -47°C or lower.

Cooling may be applied during the separation stage of the second hydrotreated effluent (106) to an extent that the second hydrotreated liquid (108) has a temperature below the inlet temperature of the first catalytic zone (102) of the first hydrotreatment reactor (101).

A hydrocarbon diluting agent as well as a fresh oxygenated hydrocarbon feedstock is not intended to be introduced to the first catalytic zone of the hydrotreatment reactor (102).

The extent of hydrodeoxygenation and hydrodenitrification in the second catalytic zone (105) may controlled in such a manner that in the first catalytic zone (102), the temperature increase between the inlet of the first catalytic zone and the outlet of the first catalytic zone is not more than 10 °C.

The second catalytic zone (105) in the hydrotreatment reactor (101) may have a lower hydrodeoxygenation activity than the first catalytic zone (102) in the hydrotreatment reactor (101). The hydrogen-rich gas (120) used in the first catalyst zone (102) may contain <5 wppm nitrogen impurities, measured as elemental nitrogen.

The inlet temperature and pressure of the second catalyst zone (105) may be 200-400 °C and 10-150 bar, such as 250-380 °C and 20-120 bar, such as 280-360 °C and 30-100 bar.

The second catalytic zone of the hydrotreatment reactor may comprise one or more catalyst(s) selected from hydrogenation metal on a support, such as for example a catalyst selected from a group consisting of Pd, Pt, Ni, Co, Mo, Ru, Rh, W or any combination of these, preferably the second catalytic zone comprise one or more catalyst(s) selected from CoMo, NiMo, NiW, CoNiMo on a support, for example an alumina support.

The hydrotreatment reactor (101) may be operated at a WHSV in the range from 0.5-3 h’ ¹ ; and a H ₂ flow of 350-900 NI H ₂ /l feed.

The inlet temperature and pressure of the first catalyst zone (102) may be 250-450 °C and 10-150 bar, such as 300-430 °C and 20-120 bar, such as 330-410 °C and 30-100 bar.

The first catalytic zone of the hydrotreatment reactor comprises one or more catalyst(s), which may be selected from hydrogenation metal compound on a support, such as for example a catalyst selected from a group consisting of Pd, Pt, Ni, Co, Mo, Ru, Rh, W or any combination of these, preferably the first catalytic zone comprise one or more catalyst(s) selected from CoMo, NiMo, NiW, CoNiMo on a support, for example an alumina support.

The inlet temperature and pressure of the isomerisation reactor (103) may be 280-370 °C and 20-50 bar.

The catalytic zone of the isomerisation reactor comprise one or more catalyst(s), which may comprise a Group VIII metal on a support, where the support is selected from silica, alumina, clays, titanium oxide, boron oxide, zirconia, which can be used alone or as a mixture, preferably silica and/or alumina.

The catalytic zone of the isomerisation reactor may further comprise a molecular sieve, such as a zeolite.

The isomerisation reactor (103) may be operated at a WHSV in the range from 0.5-1 h’ ¹ ; and a H ₂ flow of 300-500 Nl H ₂ /l feed.

The isomerised liquid may have an i- to n-paraffin ratio above 1 , such as from 5 to 30 or from 15 to 30.

Part of the first hydrotreated effluent from the first catalytic zone (102) may be used to heat the hydrotreatment entry stream, e.g. by mixing.

The oxygenated hydrocarbon feedstock may have a nitrogen impurity 300 wppm or more, preferably 500 wppm or more, measured as elemental nitrogen.

The hydrotreatment entry stream may have a nitrogen impurity of 100 to 500 wppm.

The second hydrotreated effluent (106) from the second catalytic zone may have a nitrogen impurity of 100 to 500 wppm or more.

Brief Description of the Drawings

Figure 1 shows a process scheme with a hydrotreating reactor (101) comprising a first catalytic zone (102) (polishing bed) arranged above a second catalytic zone (105) (hydrotreatment bed), and a first isomerisation reactor (103).

Figure 2 shows a comparative process scheme not according to the present invention having a first hydrotreating reactor (201) and a first isomerisation reactor (203) shows a comparative process scheme not according to the present invention having a first hydrotreating reactor (301), a second hydrotreating reactor

(302) and a first isomerisation reactor (303).

Detailed Description of the Invention

In describing the embodiments of the invention specific terminology will be resorted to for the sake of clarity. However, the invention is not intended to be limited to the specific terms so selected, and it is understood that each specific term includes all technical equivalents which operate in a similar manner to accomplish a similar purpose.

The present invention relates to a process for preparing hydrocarbons from an oxygenated hydrocarbon feedstock having a nitrogen impurity of 10 wppm or more, measured as elemental nitrogen, comprising:

- a hydrotreatment reactor (101) comprising a first catalytic zone (102) arranged above a second catalytic zone (105), in which a hydrotreatment entry stream comprising the oxygenated hydrocarbon feedstock (104), a hydrogen-rich gas (120), and optionally a product recycle diluting agent (108, 126), is introduced to the second catalytic zone (105) at an inlet between the first (102) and the second catalytic zone (105), where it is mixed with part of a first hydrotreated effluent from the first catalytic zone, where the second catalytic zone is operated at a temperature and a pressure causing at least hydrodeoxygenation and hydrodenitrification to an extent where a second hydrotreated effluent (106) from the second catalytic zone (105) of the hydrotreatment reactor contains mainly hydrocarbons, and wherein the oxygenated hydrocarbon feedstock has been converted to >95% hydrocarbons;

- the second hydrotreated effluent from the second catalytic zone of the hydrotreatment reactor is subjected to a separation stage (107) where at least part of the second hydrotreated effluent (106) is separated into a gaseous fraction (121) and a hydrotreated liquid (108), where the hydrotreated liquid contains >95 wt% hydrocarbons and >1 wppm nitrogen;

- at least part of the hydrotreated liquid (108) and a hydrogen-rich gas (120) is introduced in the hydrotreatment reactor (101) to the first catalytic zone (102), at an inlet temperature that is higher than the inlet temperature in the second catalyst zone of the hydrotreatment reactor and at a pressure causing hydrodeoxygenation and hydrodenitrification;

- a product product side stream (112) containing part of the first hydrotreated effluent from the first catalytic zone (102) is taken out between the first and second catalytic zones, the product product side stream (112) containing a liquid component and a gaseous component, and where the liquid component of the side stream contains >99 wt% hydrocarbons and <1 wppm nitrogen, preferably <0.4 wppm nitrogen, such as <0.3 wppm nitrogen (the ASTM D4629 detection), measured as elemental nitrogen.

That is, the inventors of the present invention in a first aspect of the invention found that oxygenated hydrocarbons containing a nitrogen impurity amount can be effectively hydrotreated in two catalytic zones within a reactor, when ammonia and other low boiling amines are removed from the effluent from the second catalytic zone (105) (hydrotreating zone) by separation into a gaseous and a liquid phase, followed by hydrotreating the liquid phase therefrom in a first catalytic zone (102) (polishing zone), in which this liquid phase is neither combined with other oxygenated hydrocarbon feeds, nor combined with other feeds having a higher nitrogen content than the first hydrotreated liquid. At least part of the first hydrotreated effluent is taken out as a product product side stream (112) and separated into a gaseous stream and a second hydrotreated liquid stream, which separation may be a stripping step or be followed by a stripping step (114), where the first hydrotreated liquid stream may be stripped with a stripping gas, such as hydrogen to lower the nitrogen content of the stripped side stream (115) to 0.4 wppm or lower, such as <0.3 wppm nitrogen (the ASTM D4629 detection).

Specifically, the inventors have found that gaseous ammonia present in the hydrogen-rich effluent gas, which has been formed from the nitrogen impurities of the feed during hydrotreating, can be reincorporated into the product during deeper hydrodeoxygenation/hydrodenitrification conditions, if hydrogen-rich gas containing such ammonia impurities is used in a polishing step without prior removal of the ammonia impurity. By using a polishing zone (first catalytic zone) upstream of a hydrotreating zone (second catalytic zone) fresh hydrogen can be better utilised compared to a reactor with a polishing zone downstream of a hydrotreating zone. This is because the feed to the first catalytic zone (102) (polishing zone) already contains lower amounts of nitrogen compared to the oxygenated hydrocarbon feed to the second catalytic zone (105) (hydrotreating zone), and the fresh hydrogen added to the polishing zone will not contain the nitrogen impurities that are present in the effluent from the second catalytic zone, and at the same time, the excess hydrogen present in the effluent from the first catalytic zone (102) (polishing zone) remains of a suitable quality for use in the second catalytic zone (105) (hydrotreating zone).

The reactor setup and process of the present invention causes a more efficient hydrogen usage while at the same time ensuring low amounts of nitrogen impurities of the product side stream (112).

The process is for preparing hydrocarbons from an oxygenated hydrocarbon feedstock. Examples of oxygenated hydrocarbon feedstocks are fatty acids and triglycerides, which are present in large amounts in plant oils and animal fats. An oxygenated hydrocarbon feedstock of renewable origin, such as plant oils and animal fats are well suited for the process. The majority of these plant oils and animal fats are composed of 25 wt% or 40 wt% or more of fatty acids, either as free fatty acids or as esters of free fatty acids. Examples of esters of free fatty acids are fatty acid glyceride esters (mono-, di- and/or tri-glyceridic) or for example the fatty acid methyl esters (FAME) or fatty acid ethyl esters (FAEE). Accordingly, the oxygenated hydrocarbon feedstocks of renewable origin may contain 40 wt% or more of fatty acids or fatty acid esters.

The renewable character of carbon-containing compositions, such as feedstocks and products, can be determined by comparing the ¹⁴ C-isotope content of the feedstock to the ¹⁴ C-isotope content in the air in 1950. The ¹⁴ C-isotope content can be used as evidence of the renewable origin of the feedstock or product.

Carbon atoms of renewable material comprise a higher number of unstable radiocarbon ( ¹⁴ C) atoms compared to carbon atoms of fossil origin. Therefore, it is possible to distinguish between carbon compounds derived from biological sources, and carbon compounds derived from fossil sources by analysing the ratio of ¹² C and ¹⁴ C isotopes. Thus, a particular ratio of said isotopes can be used to identify renewable carbon compounds and differentiate those from non-renewable i.e. fossil 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 sources is ASTM D6866 (2020). An example of how to apply ASTM D6866 to determine the renewable content in fuels is provided in the article of Dijs et al., Radiocarbon, 48(3), 2006, pp 315-323. For the purpose of the present invention, a carbon-containing material, such as a feedstock or product is considered to be of renewable origin if it contains 90% or more modem carbon, such as 100% modern carbon, as measured using ASTM D6866.

A number of plant oils and animal fats may contain typical amounts of nitrogen impurity, such as between 1 -100 ppm, which can be hydrotreated using the process of the present invention. However, the process of the present invention is advantageous from the point of view that the hydrotreatment process can convert oxygenated hydrocarbon feedstocks having a high nitrogen impurity, for example having a nitrogen impurity of 10 wppm or more. For example 300 wppm to 2500 wppm, or more, such as 500 wppm or more, for example 800 wppm or more. Oxygenated hydrocarbon feedstocks may for example have a nitrogen impurity of up to 1500 wppm, such as up to 2500 wppm. Examples of oxygenated hydrocarbon feedstocks with high nitrogen impurity are some animal fats, which can have nitrogen impurities of about 1000 wppm, for example in the range of 600 to 1400 wppm. The oxygenated hydrocarbon feedstock may be made up of a mixture of oxygenated hydrocarbons from different sources, should that be desired. For example, 50% of a palm oil having 23 ppm nitrogen impurity may be mixed with 50% animal fat having 1000 ppm nitrogen impurity to create an oxygenated hydrocarbon feedstock having a nitrogen impurity of 512 ppm. The oxygenated hydrocarbon feedstock may therefore be selected from plant oils, animal fats, or mixtures thereof.

The nitrogen impurity is measured as elemental nitrogen. One such method to measure elemental nitrogen is ASTM D4629, which is used in the range of 0.3 - 100 wppm, and another method is ASTM D572, which may be more appropriate above 100 wppm. Both methods can be used as necessary in the present invention to measure the nitrogen impurity is as elemental nitrogen.

A hydrotreatment reactor (101) comprising a first catalytic zone (102) arranged above a second catalytic zone (105) is used in the process, and the process involves flowing a hydrotreatment entry stream to a second catalytic zone (105) at an inlet between the first (102) and the second catalytic zone (105). The hydrotreatment entry stream comprises the oxygenated hydrocarbon feedstock (104), which can be selected as described above, e.g. plant oils, animal fat or mixtures thereof containing 10 wppm nitrogen or more, such as 300 wppm nitrogen or more, for example between 500-1500 wppm nitrogen.

The oxygenated hydrocarbon feedstock is mixed with part of a first hydrotreated effluent from the first catalytic zone, and optionally a product recycle diluting agent (108, 126). Using part of the first hydrotreated effluent from the first catalytic zone as a hydrocarbon diluting agent is advantageous from the point of view that it contains hydrocarbons with dissolved hydrogen, which results in a more effective hydrodeoxygenation (HDO) and hydrodenitrification (HDN) in the second catalytic zone. Using product recycle (108, 126) as a hydrocarbon diluting agent is advantageous compared to using the first hydrotreated effluent as a hydrocarbon diluting agent in that a greater volume of the first hydrotreated effluent product can be withdrawn as a product side stream (112).

Hydrocarbon diluting agents are well-known in the art, and are used to control the exothermic character of the hydrotreating reactions (e.g. HDO and HDN reactions). Additionally, hydrocarbon diluting agents can also contain dissolved hydrogen, which is required for efficient hydrotreatment, as the catalyst must both be in contact with the oxygenated hydrocarbon feedstock as well as hydrogen in order for the hydrotreating reactions to proceed.

Using part of the first hydrotreated effluent from the first catalytic zone (fig.1 , 1) as a hydrocarbon diluting agent is advantageous because it will already contain dissolved hydrogen, and it has a high temperature which can be used to heat the inlet of the second catalytic zone (105). Using as the hydrocarbon diluting agent, a mixture of both the first hydrotreated effluent from the first catalytic zone (fig.1, I) and product recycle from the second catalytic zone (108, 126), e.g. at least 10% of both, is advantageous from the point of view that fractions containing dissolved hydrogen is mixed with a product recycle from an earlier stage thereby increasing the amount of product side stream (112) that can be withdrawn, thereby increasing the throughput of the reactor compared to only using the first hydrotreated effluent (fig.1, I) as the hydrocarbon diluting agent.

Part of the first hydrotreated effluent from the first catalytic zone (102) may also be used to heat the hydrotreatment entry stream, e.g. by mixing.

As mentioned, the hydrocarbon diluting agent may be product recycle (108, 126) or a hydrocarbon of either fossil or renewable origin. It will usually be product recycle and/or the first hydrotreated effluent from the first catalytic zone. A hydrocarbon diluting agent is typically added in amounts ranging from 1 :1 to 4:1 (total hydrocarbon diluting agent : total oxygenated feedstock). As mentioned, the hydrocarbon diluting agent may be of fossil or renewable origin. Some hydrocarbon feeds of fossil origin can contain a high amount of nitrogen impurities. These hydrocarbon feeds of fossil origin may also be part of the hydrocarbon diluting agent, alone or in admixture with other hydrocarbon diluting agent(s), such as product recycle and/or the first hydrotreated effluent from the first catalytic zone. For example the hydrocarbon diluting agent may be a mixture of product recycle and fossil hydrocarbons.

The product recycle and the first hydrotreated effluent from the first catalytic zone are advantageous to use as they will typically contain dissolved hydrogen, which is relevant for the hydrotreatment reaction that depends on hydrogen being dissolved in the liquid phase.

The hydrotreatment entry stream may have a nitrogen impurity of 100 wppm or more, e.g. from 100 to 500 wppm, and/or the second hydrotreated effluent (106) from the second catalytic zone may have a nitrogen impurity of 100 wppm or more, e.g. from 100 to 500 wppm or more. The process of the present invention is advantageous from the point of view that the hydrotreatment process can convert oxygenated hydrocarbon feedstocks having a high nitrogen impurity without the need for extensive dilution to reduce the overall nitrogen impurity of the hydrotreatment entry stream. This is advantageous, as an extensive dilution would decrease the throughput of oxygenated hydrocarbon feedstock in the hydrotreating process. Alternatively, or additionally, the nitrogen content may also be measured in the second hydrotreated effluent (106) from the second catalytic zone, which may have a nitrogen impurity of 100 wppm or more, e.g. from 100 to 500 wppm or more.

As to the maximum amount of nitrogen impurity that may be present. There will be limitations as to how much nitrogen impurity that is present as impurities or how high an impurity amount it is practically feasible to remove. Accordingly, the hydrotreatment entry stream and/or the second hydrotreated effluent (106) from the second catalytic zone may have a nitrogen impurity of up to 500 wppm or less, i.e. the hydrotreatment entry stream and/or the second hydrotreated effluent (106) from the first hydrotreatment reactor may have a nitrogen impurity of between 100 and 500 wppm.

The hydrotreatment entry stream is introduced together with a hydrogen-rich gas (120) to a hydrotreatment reactor (101) comprising a first catalytic zone (102) arranged above a second catalytic zone (105).

The hydrogen-rich gas (120) is necessary to perform i.a. the hydrodeoxygenation (HDO) and hydrodenitrification (HDN) reactions in the first and second catalytic zones (102, 105) of the hydrotreatment reactor (101). The hydrogen-rich gas may for example be excess hydrogen from the process (123, 118) that has been purified by one or more purification steps (122), such as for example separation (122) into a gaseous fraction (123) comprising hydrogen, water, ammonia and other lights followed by amine scrubbing and/or membrane separation. The purity of the hydrogen-rich gas used in the second catalytic zone is not as important as the purity of the hydrogen-rich gas used for the first catalytic zone (102), used for stripping before the isomerisation reactor (114) or used in the isomerisation reactor (103), which suitably does not contain any reactive nitrogen, such as ammonia, such as less than 0.3 w-ppm nitrogen, measured as elemental nitrogen. Typically, it is acceptable that the hydrogen-rich gas used for the second catalytic zone has a purity of 95 mol% or higher, but it is also possible that it has a hydrogen purity that is lower than 95 mol%. Make-up hydrogen can also be mixed to form the hydrogen- rich gas, or the hydrogen-rich gas can be entirely made up of make-up gas.

The hydrotreatment reactor (101) is a vessel that can house the at least two catalytic zones (102, 105). In the present invention a trickle-bed reactor is well-suited. A trickle bed reactor involves the downward movement of the hydrotreatment entry stream while it is contacted with hydrogen in a co-current or counter-current manner. An example of a trickle bed reactor is an adiabatic trickle-bed reactor.

The hydrotreatment reactor (101) comprises a first catalytic zone (102) arranged above a second catalytic zone (105). A catalytic zone may in its simplest form be a fixed bed of catalyst particles. A catalytic zone may contain a single fixed bed or may contain multiple fixed beds having the same or different catalyst particles, or it may be a number of layers of catalyst particles of different activity and/or composition.

The first catalytic zone (102) may be a single fixed bed, and/or the second catalytic zone (105) may comprise at least three fixed beds.

The hydrotreatment entry stream is introduced together with a hydrogen-rich gas (120) to the second catalytic zone (105) at an inlet between the first (102) and the second catalytic zone (105)

The hydrotreatment entry stream is introduced together with a hydrogen-rich gas (120) into the second catalytic zone at an inlet temperature and a pressure causing at least hydrodeoxygenation and hydrodenitrification to an extent where a second hydrotreated effluent (106) from the second catalytic zone (105) of the hydrotreatment reactor contains mainly hydrocarbons.

There are many different combinations of inlet temperatures and pressures, which would cause HDO and HDN to an extent that oxygen is removed from the oxygenated hydrocarbons thereby producing water as a by-product, and that the nitrogen impurities are removed from the oxygenated hydrocarbons thereby producing ammonia as a by-product, thereby obtaining a product containing mainly hydrocarbons.

For example, the inlet temperature and pressure of the second catalyst zone (105) may be 200-400 °C and 10-150 bar, such as 250-380 °C and 20-120 bar, such as 280-360 °C and 30-100 bar.

It is a matter of routine work for the skilled person to select various combinations of temperatures and pressures causing at least hydrodeoxygenation and hydrodenitrification to an extent where the second hydrotreated effluent (106) from the second catalytic zone contains mainly hydrocarbons, wherein the oxygenated hydrocarbon feedstock has been converted to >95% hydrocarbons, suitably >98% hydrocarbons, where <2% of the oxygenated hydrocarbon feedstock is present.

In the same manner that the skilled person can select various combinations of temperatures and pressures, he would also be able to select one or more suitable catalysts for the catalytic zone of the second catalytic zone (105).

For example, the second catalytic zone of the hydrotreatment reactor may comprise one or more catalyst(s) selected from hydrogenation metal on a support, such as for example a catalyst selected from a group consisting of Pd, Pt, Ni, Co, Mo, Ru, Rh, W or any combination of these, preferably the second catalytic zone comprise one or more catalyst(s) selected from CoMo, NiMo, NiW, CoNiMo on a support, for example an alumina support.

The hydrotreatment reactor (101) may be operated at a WHSV in the range from 0.5-3 h’ ¹ ; and a H ₂ flow of 350-900 NI H ₂ /l feed.

More general reaction conditions for the second catalytic zone (105) may involve a trickle-bed reactor as the hydrotreating reactor (101), comprising the second catalytic zone, the catalytic zone comprising a supported hydrogenation catalyst comprising molybdenum, where the hydrotreatment is conducted in the presence of hydrogen at a temperature of 200-400 °C and at a pressure between 10-150 bar, where the WHSV is in the range from 0.5-3 h’ ¹ , and at a H2 flow of 300-2100 Nl H2/I feed.

The second catalytic zone will generate a second hydrotreated effluent (106), which will contain gaseous components in the form of excess hydrogen, water vapour produced from HDO, CO and CO2 produced from decarboxylation/decarbonylation of carboxylic acids in the oxygenated hydrocarbon feed as well as H2S. Finally, NH3 will be produced from the HDN reaction. Much more ammonia (NH3) will be produced in the process where oxygenated hydrocarbon feedstock comprising nitrogen impurities of 300 wppm or more, than during hydrotreatment of normal feeds e.g. having the typical amounts of 1 -100 ppm nitrogen, such as palm oil, which, for example, may have 23 ppm nitrogen. The inventors surprisingly found that especially the increased amount of ammonia in the hydrotreatment effluent from oxygenated hydrocarbon feedstock comprising nitrogen impurities of 300 wppm or more caused reincorporation of nitrogen, when the hydrotreated effluent was subjected to a further hydrotreatment step with added make-up hydrogen. That is, the inventors saw that a further hydrotreatment effluent from an additional hydrotreatment step contained 2-5 ppm nitrogen even after stripping with hydrogen gas, i.e. even if there was a desire to remove nitrogen as completely as possible before contacting with an isomerisation catalyst, it was simply not possible to get the nitrogen amount below 2-5 ppm, even after stripping. This was quite unexpected, as the additional hydrotreatment step was conducted at higher temperatures with the specific expectation of preforming a deeper HDO and HDN hydrotreatment, thereby removing more extensively oxygen and nitrogen from the second hydrotreatment effluent. Further, it was expected that the already formed hydrocarbons should be inert to any reaction with ammonia, and even if ammonia should react to generate amines or amides under the conditions of the additional hydrotreatment step, that even if there was a theoretical possibility that such nitrogen compounds would form, that these formed compounds would again undergo hydrodenitrification (HDN) removing therefrom ammonia. However, it was surprisingly found that nitrogen compounds were generated that did not disappear again under the hydrotreatment conditions in an additional hydrotreatment step. Those compounds included secondary and tertiary amides. As it is known in the art, nitrogen may deactivate the isomerisation catalyst, which is why ammonia contained in an effluent going to an isomerisation reactor is typically stripped with a stripping gas, causing any dissolved ammonia to be displaced/stripped by the stripping gas thereby removing any remaining amounts of nitrogen. As was found by the inventors in comparative examples 1 and 2, the absence of a separation step between the first and second hydrotreating step (corresponding to the second catalytic zone and first catalytic zone, respectively), when hydrotreating oxygenated hydrocarbon feedstocks, will cause a higher nitrogen content to be present to be fed to the isomerisation reactor, which in turn causes a lower yield of aviation fuel cut having a cloud point of -40°C or lower.

It was an unexpected discovery that ammonia in the first hydrotreated effluent of figures 2 and 3 caused reincorporation of nitrogen in the second hydrotreatment reactor, and that these nitrogen compounds were also unexpectedly resilient to the HDN conditions, which caused the normal removal of any residual ammonia in the stripping step prior to isomerisation to be ineffective. This was surprising to the inventors, who modified the hydrotreatment steps by including a separation stage after the first hydrotreatment reactor, in such a way that the second hydrotreated effluent from the second catalytic zone of the hydrotreatment reactor is subjected to a separation stage (107) where at least part of the second hydrotreated effluent (106) is separated into a gaseous fraction (121) and a hydrotreated liquid (108).

The separation stage (107) may be for example one or more high-pressure or low-pressure separators, that are known in the art to be able to separate the second hydrotreated effluent (106) into a gaseous fraction (121) and a second hydrotreated liquid (108). Hydrogen stripping may also be used for the separation (not shown in the figure). The separation stage may entirely be a high temperature separation stage, where the effluent is not actively cooled. Not cooling the first hydrotreatment effluent is beneficial from the point of view that less heating is required in the first catalytic zone. It may also be beneficial, if the separated second hydrotreated liquid is used as a product recycle to dilute the oxygenated hydrocarbon feedstock. The separation stage may also involve a low temperature separation, where the hydrotreated effluent is actively cooled by e.g. a heat exchanger, as this is beneficial from the point of view that as much ammonia as possible is separated from the first hydrotreated liquid. Accordingly, cooling may be applied during the separation stage of the second hydrotreated effluent (106) to an extent that the second hydrotreated liquid (108) has a temperature below the inlet temperature of the first catalytic zone (102) of the hydrotreatment reactor (101), such as at least 100 °C below the inlet temperature of the first hydrotreatment reactor. Cold separation of the first hydrotreatment effluent may for example be performed at temperatures between 120 and 200 °C.

The entire amount of the second hydrotreated effluent (106) may be separated, or at least part of the second hydrotreated effluent (106) may be separated. For example, the second hydrotreated effluent may be split into two streams, where one stream is separated into a second hydrotreated liquid (108) and a gaseous fraction (121) as described above, and where the other stream is used as a hydrocarbon diluting agent without any separation. The other stream would in addition to hydrocarbons also include both the excess hydrogen as well as all the gaseous impurities, including ammonia, which would be reintroduced into the second catalytic zone.

The entire amount of the second hydrotreated effluent (106) may also be separated to avoid ammonia build-up in the second catalyst zone or to avoid adding further amounts of ammonia to the second catalyst zone (when the second hydrotreating effluent is used as product recycle), which could react with the oxygenated hydrocarbons to form further nitrogen compounds, which could then be present in the second hydrotreating effluent.

In the separation stage (107), the second hydrotreated effluent (106) is separated into a gaseous fraction (121) and a second hydrotreated liquid (108). The gaseous fraction (121) will comprise excess hydrogen, water vapour produced from HDO, CO and CO2 produced from decarboxylation/decarbonylation of carboxylic acids in the oxygenated hydrocarbon feed as well as H2S. Finally, NH3 will be produced from the HDN reaction. The second hydrotreated liquid (108) will contain >90 wt% hydrocarbons, the remainder being heteroatom-containing hydrocarbons, such as unreacted oxygenated hydrocarbons. It is desirable that the hydrotreatment is as complete as possible, i.e. that the second hydrotreated liquid (108) contains >95 wt% hydrocarbons, such as >98 wt% hydrocarbons. However, it is not always feasible or possible to completely hydrotreat the hydrotreatment entry stream without increasing the seventy of the reaction conditions, which could cause coking of the catalyst, and other undesirable side effects. Accordingly, the conversion may be such that the second hydrotreated liquid (108) also contains <99 wt% hydrocarbons, i.e. the hydrotreatment entry stream is hydrotreated to an extent that the second hydrotreated liquid (108) contains between 95 and 99 wt% hydrocarbons.

The remaining components of the first hydrotreated liquid would be heteroatom-containing hydrocarbons, such as oxygenated hydrocarbons or nitrogen containing hydrocarbons. When the initial nitrogen impurity is very high, the nitrogen will still remain to some extent in the first hydrotreated liquid, which may contain >1 wppm nitrogen, measured as elemental nitrogen, such as >5 wppm, and up to 100 wppm.

The second hydrotreated liquid (108) containing nitrogen impurities of e.g. 5-100 wppm, or at least part of the second hydrotreated liquid (108) is introduced in the first catalytic zone (102) together with a hydrogen-rich gas (120).

The hydrogen-rich gas (120) is necessary to perform i.a. the hydrodeoxygenation (HDO) and hydrodenitrification (HDN) reactions not only in the second catalytic zone (105) as explained above, but also in the first catalytic zone (102). The hydrogen- rich gas may for example be excess hydrogen from the process (123, 118) that has been purified by one or more purification steps (122), such as for example separation (122) into a gaseous fraction (123) comprising water, ammonia and other lights followed by amine scrubbing and/or membrane separation. The purity of the hydrogen-rich gas used in the second catalytic zone is not as important as the purity of the hydrogen-rich gas used for the first catalytic zone (102), used for stripping before the isomerisation reactor (114) or used in the isomerisation reactor (103). The hydrogen-rich gas used for the first catalytic zone typically has a purity of 90 mol%, often 95 mol% or higher, and may contain gaseous hydrocarbons. As it is intended to reduce as much as possible the risk of reincorporating nitrogen into the first hydrotreatment effluent, withdrawn as a product side stream (112), the hydrogen-rich gas used for the first catalytic zone (102) ideally has very little or no reactive nitrogen, such as ammonia. Specifically, the nitrogen content in the hydrogen-rich gas (120) used for the first catalytic zone (102) reactor should ideally not cause an increase in the nitrogen content of the liquid phase of the feed (127+102) for the first catalytic zone (102) when it is mixed with the first hydrotreated liquid (127) to form the feed (127+102) to first catalytic zone (102).

The hydrogen-rich gas (120) used in the first catalyst zone (102) may therefore contain <10 wppm nitrogen impurities or lower, such as <5 wppm nitrogen impurities, measured as elemental nitrogen, such as <1 wppm nitrogen impurities, measured as elemental nitrogen.

The hydrogen-rich gas may be the excess hydrogen gas that has been purified, the so-called hydrogen recycle, if that has a sufficient quality. The hydrogen-rich gas may also be fresh hydrogen, which has not yet been used in the process, and it may be a mixture of the hydrogen recycle and fresh hydrogen.

As will be appreciated by the skilled person, when reference is made to nitrogen impurities, it is intended to cover nitrogen impurities, which under the hydrotreating or hydroisomerisation conditions can be considered to react to form new bonds, i.e. non-inert or reactive nitrogen. For example, nitrogen that is capable of being incorporated into the products and intermediates of the present invention, such as the second hydrotreated effluent (106), the first hydrotreatment effluent, withdrawn as a product side stream (112), or the isomerisation effluent (116) is considered to be nitrogen impurities according to the present invention. It is not intended that nitrogen gas (N2) should fall within the term nitrogen impurities, as it is used in the present invention. Nitrogen impurities can be determined using elemental analysis and cover organic nitrogen, ammonia, and ammonium. As referred to above, the hydrotreatment reactor (101) comprises a first catalytic zone (102) arranged above a second catalytic zone (105). The first catalytic zone (102) may be a single fixed bed.

At least part of the second hydrotreated liquid (108, 127) is introduced together with a hydrogen-rich gas (120) to a first catalytic zone (102), at an inlet temperature and a pressure causing at least hydrodeoxygenation and hydrodenitrification, to an extent where the liquid component of the side stream contains >99 wt% hydrocarbons and <1 wppm nitrogen, preferably <0.4 wppm nitrogen, such as <0.3 wppm nitrogen (the ASTM D4629 detection), measured as elemental nitrogen.

Specifically, the nitrogen content of the liquid component of the product side stream (112) is lower than the nitrogen content of the second hydrotreated liquid (108).

It is not required nor intended that the second hydrotreated liquid should be diluted with any diluting agent, such as hydrocarbons, before or during hydrotreatment in the first catalytic zone (102). Rather the second hydrotreated liquid (108, 127) is used as the feed to the second hydrotreating reactor. However, it is possible to mix the second hydrotreated liquid (108, 127) with another hydrocarbon feed, as long as the second hydrotreated liquid (108, 127) is not mixed with a feed having an oxygen content that is higher than the oxygen content of the second hydrotreated liquid (108, 127), and where the second hydrotreated liquid (108, 127) is preferably not mixed with a feed having a nitrogen content of >100 wppm;

A hydrocarbon diluting agent is not necessary to control the exothermic character of the hydrotreatment reactions in the first catalytic zone. Accordingly, a diluting agent, such as a hydrocarbon diluting agent may therefore be absent in the second hydrotreatment reactor, i.e. a hydrocarbon diluting agent is in some cases not introduced to the first catalytic zone of the hydrotreatment reactor (102).

There are many different combinations of inlet temperatures and pressures, which would cause HDO and HDN to an extent that oxygen is removed from the remaining oxygenated hydrocarbons thereby producing water as a by-product, and that the nitrogen impurities are further reduced compared to the second hydrotreated liquid (108) thereby producing ammonia as a byproduct, and a liquid component of the product side stream (112) containing a lower amount of nitrogen impurities than the second hydrotreated liquid (108).

Specifically, the inlet temperature in the first catalyst zone (102) is higher than the inlet temperature in the second catalyst zone (105) of the hydrotreatment reactor

(101)

For example, the inlet temperature and pressure of the first catalytic zone (102) may be 250-450 °C and 10-150 bar, such as 300-430 °C and 20-120 bar, such as 330-410 °C and 30-100 bar.

In order to cause a deeper HDO and HDN reaction, the inlet temperature of the first catalytic zone (102) is higher than compared to the inlet temperature of the second catalytic zone (105). For example, the inlet temperature of the first catalytic zone

(102) may be 10-15 °C higher than the inlet temperature for the second catalytic zone (105), or even higher.

As the amount of oxygenated hydrocarbons are significantly less in the second hydrotreated liquid (108, 127) compared to the hydrotreatment entry stream to the second catalytic zone (105), this means that the temperature rise over the first catalytic zone (102) is not as high as in the second catalytic zone (105) due to the fact that less exothermic reactions occurs.

For example, the temperature increase between the reactor inlet and the reactor outlet of the second hydrotreatment reactor may be small, such as no more than 35 °C, or it can be considered as being 50% or less of the temperature rise in the first hydrotreatment reactor.

Accordingly, the extent of hydrodeoxygenation and hydrodenitrification in the second catalytic zone (105) may controlled in such a manner that in the first catalytic zone (102), the temperature increase between the inlet of the first catalytic zone and the outlet of the first catalytic zone is not more than 10 °C. This can be controlled by ensuring a sufficient conversion of the oxygenated hydrocarbon feed in the first hydrotreatment reactor, leaving only a small amount of hydrocarbons having heteroatoms such as oxygen and nitrogen in the first hydrotreated liquid, which will then result in a smaller temperature rise due to the amount of material remaining that undergoes the exothermic hydrotreatment reactions.

The second catalytic zone (105) in the hydrotreatment reactor (101) may have a lower hydrodeoxygenation activity than the first catalytic zone (102) in the hydrotreatment reactor (101).

To increase the hydrotreating activity in the first catalytic zone, it is possible to increase the temperature, as mentioned above, in order to obtain more extensive HDO and HDN reactions. It is also possible to increase the hydrotreating activity by ensuring that the first catalytic zone (102) has a higher hydrodeoxygenation activity than the second catalytic zone (105).

The catalytic activity may also start out by being the same in both the first and second catalytic zones, e.g. by using a catalyst having the same activity in both reactors. Over time the second catalytic zone (105) will deactivate faster than the first catalytic zone (102) because a more impure feed, the hydrotreatment entry stream, is provided to the second catalyst zone, whereas a more pure feed, the second hydrotreated liquid (108, 127), is provided to the first catalytic zone (102). Accordingly, the second catalytic zone (105) may have a lower hydrodeoxygenation activity than the first catalytic zone (102). Catalytic activity can be measured compared to the fresh catalyst.

In the same manner that the skilled person can select various combinations of temperatures and pressures in the second catalytic zone, he would also be able to select one or more suitable catalysts and conditions to cause more extensive HDO and HDN reactions in the first catalytic zone.

The first catalytic zone of the hydrotreatment reactor comprise one or more catalyst(s), which may be selected from hydrogenation metal on a support, such as for example a catalyst selected from a group consisting of Pd, Pt, Ni, Co, Mo, Ru, Rh, W or any combination of these. For example, the catalytic zones may comprise one or more catalyst(s) selected from CoMo, NiMo, NiW, CoNiMo on a support, for example an alumina support. When the catalyst is selected from the group consisting of Ni, Co, Mo, Ru, Rh, W or any combination of these, then typically the catalyst is sulfided, and a source of sulfur is either added or present in the hydrotreatment entry stream and/or in the hydrogen-rich gas.

The first catalytic zone of the hydrotreatment reactor may be operated at a WHSV in the range from 0.5-3 h’ ¹ , such as 0.5-1.5 IT ¹ and a H2 flow of 350-2100 NI H2/I feed, such as 500-1500 NI H ₂ /l feed.

More general reaction conditions for the first catalytic zone may involve a trickle-bed reactor comprising the first and second catalytic zone, the catalytic zone comprising a supported hydrogenation catalyst comprising molybdenum, where the hydrotreatment is conducted in the presence of hydrogen at a temperature of 250-400 °C and at a pressure between 10-150 bar, where the WHSV is in the range from 0.5-3 hr ¹ , and at a H ₂ flow of 500-2100 NI H ₂ /l feed.

A product product side stream (112) containing part of the first hydrotreated effluent from the first catalytic zone (102) is taken out between the first and second catalytic zones. The first hydrotreated effluent may e.g. be collected in a tray having one or more overflow weirs or chimneys to allow effluent gas (fig.1 , g) to pass downstream to the second catalytic zone (105), and to allow overflow (fig.1 , I) of the first hydrotreated effluent to pass downstream to the second catalytic zone.

A product product side stream (112) containing a liquid component and optionally a gaseous component can be withdrawn between the first catalytic zone and the second catalytic zone. The liquid component of the side stream contains >99 wt% hydrocarbons and <1 wppm nitrogen, preferably <0.4 wppm nitrogen, such as <0.3 wppm nitrogen (the ASTM D4629 detection), measured as elemental nitrogen.

The product side stream (112) may for example be subject to one or more high- pressure or low-pressure separators, that are known in the art to be able to separate the product side stream (112) into a liquid fraction and a gaseous fraction. The separation stage may entirely be a high temperature separation stage, where the product side stream (112) is not actively cooled. Not cooling the product side stream (112) is beneficial from the point of view that less heating is required in any following steps, such as an isomerisation step.

The separation stage (114) may be a stripper, which uses a gas, usually hydrogen, to remove impurities in the product side stream (112) or the liquid component of the product side stream (112). Hydrogen is usually used as a stripping gas, because the stripping stage then both serves the purpose of removing impurities as well as ensuring that a certain amount of hydrogen is dissolved in the liquid component of the side stream (112) and/or the stripped liquid side stream (115), which is beneficial if these liquids are taken to e.g. a hydroisomerisation stage, such as the isomerisation reactor (103). The nitrogen content of the liquid component of the product side stream (112) as well as the stripped liquid side stream (115), if stripping is used, is lower than the nitrogen content of the second hydrotreated liquid (108).

Accordingly, the product side stream (112) from the first catalytic zone (102) may be stripped with a stripping gas (e.g. hydrogen) subjected to a stripping stage (114) causing the stripped liquid side stream (115) to have <0.4 wppm nitrogen, such as <0.3 wppm nitrogen (the ASTM D4629 detection limit), measured as elemental nitrogen.

A stripping stage using hydrogen is beneficial to use in order to both remove impurities as well as ensuring that a certain amount of hydrogen is dissolved in the liquid phase, as explained above. A stripping stage is in particular useful, when liquids are taken to e.g. a hydroisomerisation stage, such as the isomerisation reactor (103).

The product side stream (112) may be used as a product of its own, or it may be further refined by isomerised.

The product side stream (112) may be isomerised in an isomerisation reactor (103) comprising at least one catalytic zone, in which the product side stream (112) and a hydrogen-rich gas (120), which hydrogen-rich gas may contain <1 ppm (mol/mol) nitrogen, measured as elemental nitrogen, is introduced into the catalytic zone at an inlet temperature and a pressure causing at least hydroisomerisation to produce an isomerised effluent (116).

A hydrogen-rich gas (120) is also necessary to perform the hydrodeoxygenation (HDO) and hydrodenitrification (HDN) in the first and second catalyst zones (102, 105) as explained above, but also in the isomerisation reactor (103).

The hydrogen-rich gas may for example be excess hydrogen from the process (123, 118) that has been purified by one or more purification steps (122), such as for example separation (122) into a gaseous fraction (123) comprising water, ammonia and other lights followed by amine scrubbing and/or membrane separation. The purity of the hydrogen-rich gas used in the isomerisation reactor is important.

The hydrogen-rich gas used for the isomerisation reactor has a purity of 95% or higher. As it is intended to reduce as much as possible the risk of poisoning the catalytic zone(s) of the isomerisation reactor. Accordingly, the hydrogen-rich gas used for the second hydrotreating reactor ideally has very little or no reactive nitrogen, such as ammonia.

The hydrogen-rich gas (120) used in the isomerisation reactor (103) may therefore contain <1 ppm (mol/mol) nitrogen impurities, measured as elemental nitrogen. The hydrogen-rich gas may be the excess hydrogen gas that has been purified, the so- called hydrogen recycle, if that has a sufficient quality. The hydrogen-rich gas may also be fresh hydrogen, which has not yet been used in the process, and it may be a mixture of the hydrogen recycle and fresh hydrogen.

As will be appreciated by the skilled person, when reference is made to nitrogen impurities, it is intended to cover nitrogen impurities, which under the hydrotreating or hydroisomerisation conditions can be considered to react to form new bonds, i.e. non-inert or reactive nitrogen. For example nitrogen that is capable of being incorporated into the products and intermediates of the present invention, such as the first or second hydrotreating effluent, or the first isomerisation effluent is considered to be nitrogen impurities according to the present invention. It is not intended that nitrogen gas (N2) should fall within the term nitrogen impurities, as it is used in the present invention. The sulfur impurity, if any, should also be low, when the isomerisation catalyst comprises a noble metal catalyst, such as a catalyst containing Pd or Pt.

The isomerisation reactor (103) is a vessel that can house the at least one catalytic zone. In the present invention a trickle-bed reactor is well-suited. A trickle bed reactor involves the downward movement of the feed while it is contacted with hydrogen in a co-current or counter-current manner. An example of a trickle bed reactor is an adiabatic trickle-bed reactor.

The isomerisation reactor (103) comprises at least one catalytic zone. Such a catalytic zone may in its simplest form be a fixed bed of catalyst particles. It may also be multiple fixed beds having the same or different catalyst particles, or it may be a number of layers of catalyst particles of different activity and/or composition. The isomerisation reactor (103) may have a single catalytic zone.

The liquid component of the side stream(112) or the stripped side stream (115) is introduced together with a hydrogen-rich gas (120) to an isomerisation reactor (103) where it comes into contact with at least one catalytic zone, at an inlet temperature and a pressure causing at least hydroisomerisation to produce an isomerisation effluent (116), to an extent where the liquid part (119) of the isomerised effluent (116) contains >30 wt% branched hydrocarbons, and/or an increase in branched hydrocarbons of >30 wt% compared to the second hydrotreated liquid.

There are many different combinations of inlet temperatures and pressures, which would cause hydroisomerisation to an extent the isomerised effluent (116) contains >30 wt% branched hydrocarbons, and/or an increase in branched hydrocarbons of >30 wt% compared to the second hydrotreated liquid.

For example, the inlet temperature and pressure of the isomerisation reactor (103) may be 250-400 °C and 20-50 bar, such as 280-370 °C and 20-50 bar or 295-370 °C and 20-50 bar. The catalytic zones of the first isomerisation reactor may comprise one or more catalyst(s) comprising a Group VIII metal on a support, where the support may be selected from silica, alumina, clays, titanium oxide, boron oxide, zirconia, which can be used alone or as a mixture. For example, the support may be silica and/or alumina. The Group VIII metal may for example be Pd or Pt. Additionally, the one or more catalyst(s) may further comprise a molecular sieve, such as a zeolite.

The isomerisation reactor (103) may be operated at a WHSV in the range from 0.5-3 h ^-1 ; and a H2 flow of 150-800 Nl H2/I feed, for example 0.5-1 h’ ¹ ; and a H2 flow of 300-500 Nl H ₂ /l feed.

The skilled person knows how to manipulate the above conditions in order to obtain an extent of hydroisomerisation where the liquid part (119) of the first isomerisation effluent (116), contains more branched hydrocarbons compared to the liquid component of the product side stream (112). For example to such an extent that the liquid part (119) of the first isomerisation effluent (116), contains >30 wt% branched hydrocarbons, and/or an increase in branched hydrocarbons of >30 wt% compared to the second hydrotreated liquid.

The first isomerised liquid may also have been isomerised to such an extent that the iso- to n-paraffin ratio is above 1 , such as from 5 to 30, or from 15-30.

The degree of isomerisation is often measured as the difference between cloud point of the feed and the product, here between the liquid component of the product side stream (112) and the liquid part (119) of the isomerisation effluent, where a magnitude of the decrease in cloud point determines how extensive the hydroisomerisation has been. Accordingly, the first isomerised liquid may be isomerised to such an extent that the decrease in cloud point from the second hydrotreated liquid and to the liquid part (119) of the first isomerisation effluent is 10°C or more.

Normally it is considered that the lower the cloud point, the better, because this would convey good cold flow properties. However, during hydroisomerisation conditions there is also hydrocracking to some extent. In the art there is usually a point where hydrocracking becomes too extensive that the loss of liquid product outweighs the potential for a lower cloud point. The catalyst and any impurities contained therein, as well as the conditions for hydroisomerisation are among the parameters that can influence the degree of hydroisomerisation and hydrocracking. Reference is made to the comparative example 1 and example 1 , where it can be seen that the nitrogen impurity before entering the isomerization reactor is much higher in the comparative example 1 (0.6-2.9 wppm) compared to example 1 (<0.3 wppm). Such a difference in nitrogen content to the isomerisation reactor influences not only the yield of the specific fuel cut, but also significantly influences the cold flow properties thereof.

For example, the side stream may be subjected to a stripping stage (114), where the side stream (116) is stripped with a stripping gas (H2) causing the stripped side stream (115) to have <0.4 wppm nitrogen, such as <0.3 wppm nitrogen (the ASTM D4629 detection), measured as elemental nitrogen, and a lower nitrogen amount compared to the side stream (116); may be subjected to a step of isomerising this stripped side stream (115) in an isomerisation reactor (103) comprising at least one catalytic zone, in which the stripped side stream (115) and a hydrogen-rich gas (120) having, such as <0.3 wppm nitrogen (the ASTM D4629 detection), measured as elemental nitrogen, is introduced into the catalytic zone at a temperature and a pressure causing at least hydroisomerisation to produce a first isomerisation effluent (116); where the isomerised effluent from the isomerisation reactor (103) is subjected to a separation stage, where the isomerised effluent is separated into a gaseous fraction and an isomerised liquid, where the first isomerised liquid contains >30 wt% branched hydrocarbons, and/or an increase in branched hydrocarbons of >30 wt% compared to the stripped side stream (115).

More general reaction conditions for the isomerisation step may involve a tricklebed reactor as the isomerising reactor, comprising a catalyst zone, the catalyst zone comprising a supported hydrogenation catalyst comprising W or Pt or Pd, and a zeolite where the hydroisomerisation is conducted in the presence of hydrogen at a temperature of 295-370 °C and at a pressure between 20-50 bar, where the WHSV is in the range from 0.5-1 .5 h’ ¹ , and at a H2 flow of 150-800 Nl H2/I feed to such an extent that the decrease in cloud point from the second hydrotreated liquid and to the liquid part (119) of the first isomerisation effluent is reduced by 10°C or more.

The isomerised effluent (116) from the isomerisation reactor (103) is subjected to a separation stage (117), where the isomerised effluent (116) is separated into a gaseous fraction (118) and an isomerised liquid (119).

The separation stage (117) may be for example one or more high-pressure or low-pressure separators, that are known in the art to be able to separate the isomerised effluent (116) into a gaseous fraction (118) and a first isomerised liquid (119). The separation stage (117) may also be distillation, although usually it is beneficial to separate the gaseous fraction from the liquid fraction before distillation.

As mentioned above, the first isomerised liquid contains >30 wt% branched hydrocarbons, and/or an increase in branched hydrocarbons of >30 wt% compared to the second hydrotreated liquid.

The isomerised effluent (116) or the isomerised liquid (119) may be subjected to a distillation stage to produce one or more product fractions. Such fractional distillation is well-known in the art.

In particular, the process of the present invention is beneficial because it was surprisingly found that the specific conditions resulted in a large fraction of high quality aviation fuel, see example 1. The aviation fuel fraction contained the C8-C16 hydrocarbons, in particular the major part of the aviation fuel contained the C9-C12 hydrocarbons. The aviation fuel fraction may also be characterised by the distillation range, for example as having a distillation range between 150-250°C.

The isomerised liquid may be separated into at least an aviation fuel having a cloud point of -25 °C or lower, such as -30°C or lower, for example -40 °C or lower, such as -47°C or lower.

Figure 1 describes feeding oxygenated hydrocarbon feedstock (104) mixed with hydrogen-rich gas (120) and hydrocarbon diluting agent (126) in the form of product recycle to the second catalytic zone (105) of a hydrotreating reactor (101) comprising a first catalytic zone (102) upstream of a second catalytic zone (105). The second hydrotreated effluent (106) is separated into a gaseous fraction (121) and a second hydrotreated liquid (108) in separator (107). Gaseous fraction (121) may be flashed again at a lower temperature into gaseous fraction (123), water rich fraction (125), and hydrocarbon rich fraction (124) in separator (122). The first hydrotreated liquid (108) can be heated (109, 111) and recompressed (110) and mixed with hydrogen-rich gas (120) to form the feed for the first catalytic zone (102) comprising, where hydrodeoxygenation and hydrodenitrification is caused to obtain a first hydrotreating effluent, from which a product side stream (112) can be withdrawn. The product side stream (112) is stripped with hydrogen-rich gas (120) in stripper (114) to form a stripped hydrotreated liquid (115), which is mixed with hydrogen-rich gas (120) and fed to an isomerisation reactor (103) comprising at least one catalytic zone, where the stripped hydrotreated liquid (115) is isomerised to obtain an isomerised effluent (116), which is separated into a gaseous fraction (118) and a isomerised liquid (119) in separator (117). The specific arrangement makes efficient use of fresh hydrogen for polishing in the first catalytic zone, providing a polished hydrocarbon product rich in dissolved hydrogen, where part of such product (fig.1 , I (liquid overflow)) and excess hydrogen gas (fig.1 , g) can be used as hydrocarbon diluent and make-up hydrogen in the downstream hydrotreatment in the second catalytic zone, and/or withdrawn as a product side stream (112) between the polishing and hydrotreating bed and isomerised in an isomerisation reactor.

Figure 2 is a comparative reactor setup referred to in comparative example 1 and in table 7. It is similar to figure 1 , but omits the second hydrotreating reactor. Figure 2 describes feeding oxygenated hydrocarbon feedstock (204) mixed with hydrogen-rich gas (220) and hydrocarbon diluting agent (226) to a first hydrotreatment reactor (201) comprising at least one catalytic zone (205). The first hydrotreated effluent (206) is separated into a gaseous fraction (221) and a first hydrotreated liquid (208) in separator (207). Gaseous fraction (221) may be flashed again at a lower temperature into gaseous fraction (223), water rich fraction (225), and hydrocarbon rich fraction (224) in separator (222). The first hydrotreated liquid (208) is stripped with hydrogen-rich gas (220) in stripper (214) to form a stripped hydrotreated liquid (215), which is mixed with hydrogen-rich gas (220) and fed to a first isomerisation reactor (203) comprising at least one catalytic zone, where the stripped hydrotreated liquid (215) is isomerised to obtain a first isomerised effluent (216), which is separated into a gaseous fraction (218) and a first isomerised liquid (219) in separator (217).

Figure 3 is a comparative reactor setup referred to in comparative example 2 and in table 7. It is similar to figure 1 , but does not include a separation step between the first and second hydrotreating reactor. Figure 3 describes feeding oxygenated hydrocarbon feedstock (304) mixed with hydrogen-rich gas (320) and hydrocarbon diluting agent (326) in the form of product recycle to a first hydrotreatment reactor (301) comprising at least one catalytic zone (305). The first hydrotreated effluent (306) is mixed with hydrogen-rich gas (320) to form the feed for the second hydrotreating reactor (302) comprising at least one catalytic zone, where hydrodeoxygenation and hydrodenitrification is caused to obtain a second hydrotreating effluent (330), which is separated into a gaseous fraction (321) and a second hydrotreating liquid (312) in separator (307). Gaseous fraction (321) may be flashed again at a lower temperature into gaseous fraction (323), water rich fraction (325), and hydrocarbon rich fraction (324) in separator (322). The second hydrotreating liquid (312) is stripped with hydrogen-rich gas (320) in stripper (314) to form a stripped hydrotreated liquid (315), which is mixed with hydrogen-rich gas (320) and fed to a first isomerisation reactor (303) comprising at least one catalytic zone, where the stripped hydrotreated liquid (315) is isomerised to obtain a first isomerised effluent (316), which is separated into a gaseous fraction (318) and a first isomerised liquid (319) in separator (317).

When describing the embodiments of the present invention, the combinations and permutations of all possible embodiments have not been explicitly described. Nevertheless, the mere fact that certain measures are recited in mutually different dependent claims or described in different embodiments does not indicate that a combination of these measures cannot be used to advantage. The present invention envisages all possible combinations and permutations of the described embodiments. The terms “comprising”, “comprise” and comprises herein are intended by the inventors to be optionally substitutable with the terms “consisting of”, “consist of’ and “consists of”, respectively, in every instance.

Examples

Example 1. Low quality waste material originating from rendered animal fat waste containing beef tallow, pork lard and chicken fat, was used as feedstock for renewable fuel processing. The feedstock was purified using pretreatment by bleaching before directing it to a hydrotreatment process. Table 1 shows the carbon number distribution of the low-quality animal fat feedstock used before pretreatment measured by GC according to ISO 15304M.

Table 1. The carbon number distribution of the low-quality animal fat feedstock before pretreatment analyzed by GC. Table 2. Properties of the feedstock before pretreatment Table 3. Gel Permeation Chromatography (GPC) analysis on the feedstock components before pretreatment.

The feedstock was pretreated by bleaching before using it as feedstock for the hydrotreatment processing whereby the amount of nitrogen calculated as total elemental nitrogen was decreased to 1000 w-ppm, which was thus the nitrogen impurity level of the feed stream when entering it into hydrotreatment processing (see the entry “N content in the feed to HDO” in table 4).

The feedstock to be processed by hydrotreatment contained nitrogen impurities, inorganic and organic, the organic impurities being mainly in the form of organic nitrogen compounds, such as amides and amines, which were analyzed from the feed. The amount of metal impurities, such as Ca, Co, Fe, Mg, Mn, Ni and Zn, were less than 1 w-ppm which was the analysis detection accuracy limit for the specific ICP determination used. Equally, the amount of Al and Na impurities were less than 2 w-ppm, and P content was less than 1 w-ppm.

To illustrate the invention with various amounts of nitrogen, this pretreated feedstock was mixed with palm oil having a nitrogen content of 18 w-ppm to obtain six different concentrations of nitrogen (25, 75, 150, 300, 500, 1000 w-ppm) used in run 1-6 of this example.

The pretreated feedstocks containing various amounts of nitrogen (fresh feed) were introduced as six separate runs into a hydrodeoxygenation (HDO) fixed bed trickle bed reactor set-up according to figure 1. The HDO reaction was carried out in the presence of a catalyst bed (105) containing 45000 kg sulphided NiMo on alumina support (fresh catalyst having a relative HDO activity compared to fresh HDO catalyst activity), under a pressure of 50 bar, a feed rate into the HDO reactor of 48000 kg/h, a total feed rate WHSV of 1 .1 IT ¹ for catalyst bed (105), at a H2 flow of about 500 Nl H2/I feed, and at a reaction temperature of about 309 °C measured at the HDO reactor inlet (TIN), resulting in a temperature of about 340 °C at the HDO reactor outlet (TOUT). Fresh hydrogen feed into the reactor was 28700 m ³ /h (NTP) and the low-quality animal fat waste feed volume was 57 m ³ /h. Liquid HDO product was recycled as diluting agent (126), and the ratio of product recycle to the fresh feed was about 6:1 .

The effluent from the HDO reactor underwent separation into a liquid and a gaseous phase in a high temperature separator before being fed to the polishing bed (102), located upstream of the HDO bed. The polishing bed is a fixed bed containing the same sulphided NiMo catalyst on alumina support as the HDO bed (fresh catalyst having a relative HDO activity compared to fresh HDO catalyst activity), where the amount of the catalyst material was 15000 kg. The polishing bed was operated under a pressure of 50 bar, having a feed rate WHSV of about 8.2 IT ¹ when calculated based on the total liquid feed, and the polishing bed inlet temperature (TIN) was about 340 °C, /.e. 31 °C higher than the HDO inlet temperature. The hydrogen amount used was about 25 vol-% of the amount of hydrogen used in the HDO catalyst bed.

T able 4 shows the results of the test runs (run 1 -6) with a set-up as shown in figure 1 , as described above, where a combined HDO reactor and a polishing bed is used, where the gaseous by-products including nitrogen containing compounds are removed in between the two beds. As evident from table 4, the nitrogen content after the polishing step can be kept low despite very high nitrogen contents of the fresh feed. The low nitrogen amount is desirable in a product for various reasons, in particular because low nitrogen amounts influences the isomerisation reaction thereby causing better cold flow properties under identical isomerisation conditions compared to a product having a higher nitrogen amount prior to isomerisation (data not shown).

The nitrogen content may be decreased to < 0.4 w-ppm by modifying the processing conditions, in particular increasing the processing temperature of the polishing bed. The final nitrogen impurity was <0.3 w-ppm in all the runs (1 -6). Increasing the temperature in the HDO bed typically leads to uncontrollable reactions causing poor cold properties in the final isomerised product. After the hydrodeoxygenation and polishing the final liquid paraffinic effluent was hydroisomerized in an isomerization reactor. The isomerization was carried out in a fixed bed trickle bed reactor in the presence of a Pt-SAPO-catalyst under a pressure of 40 bar, with WHSV of 1 .5 IT ¹ and a reaction temperature of 328°C. Hydrogen to feed ratio was 300 normal litres H2 per litre feed.

The very low nitrogen content of all the experiments led to products with excellent cold properties. After isomerization and separation by distillation an aviation fuel cut was obtained having a T10 (°C) cut-off temperature from 185 to 205, a T90 (°C) cut-off temperature from 270 to 295 °C and final boiling point (°C) from 275 to 300 °C, fulfilling the ASTM D7566 (2016), Annex A2 specification, having a density of less than 772 kg/m ³ (measured according to ASTM 4052 (2018)) and a freezing point of less than -40 °C (measured according to IP529). The obtained aviation fuel component further has a turbidity point lower than -30 °C (determined according to ASTM D5771 (2017)) with an excellent yield of about 60 wt-%.

Table 4. HDO reactor and polishing bed - fresh catalyst - Figure 1

Comparative example 1 A reactor set-up according to figure 2 was tested as an alternative for efficiently removing the undesired oxygen and nitrogen impurities. In the set-up of figure 2, the same feed composition to example 1 was applied and essentially the same operating conditions (temperature, pressure, catalysts, etc.) were used as in example 1 , with the exception that in this reactor set-up there was no polishing bed (102) downstream of the HDO reactor. Rather in this example the entire catalyst amount of fresh catalyst (60000 kg) was in a single HDO reactor. The HDO reaction was carried out under a pressure of 50 bar, a feed rate into the HDO reactor of 48000 kg/h, a total feed rate WHSV of 0.8 h’ ¹ , at a H2 flow of about 590 Nl H2/ 1 feed, and at a reaction temperature of about 308 °C measured at the HDO reactor inlet (TIN), resulting in a temperature of about 340 °C at the HDO reactor outlet (TOUT). Fresh hydrogen feed into the reactor was 33400 m ³ /h (NTP) and the low-quality animal fat waste feed volume was 57 m ³ /h. Liquid HDO product was recycled as diluting agent, and the ratio of product recycle to the fresh feed was about 6:1 .

Table 5 shows the results from the runs in a single HDO reactor as shown in figure 2, where the gaseous by-products including nitrogen containing compounds are removed after the HDO reactor before entering the liquid paraffinic effluent into the isomerisation stage.

As can be seen from table 5, the nitrogen content before the isomerisation reactor of all runs (7-12) were higher compared to the nitrogen content in example 1. The same amount of catalyst was used in comparative example 1 compared to example 1 , but now inside a single reactor. This comparison shows that a single reactor is not able to remove the nitrogen in a similar efficient manner as in the case of splitting the catalyst volume into two separate reactors and removing the gaseous phase between these two reactors.

The increased nitrogen content in feed inevitably led to an increase of nitrogen in the final liquid paraffinic effluent stream to the isomerization thus resulting in poorer cold properties and yield for the aviation fuel component retrieved from the separation distillation after isomerization. A turbidity point of about -10 °C was obtained with aviation fuel yield of 5 wt-% in the run 12 where the nitrogen initial content was 1000 ppm.

Table 5. Single HDO reactor only - fresh catalyst - Figure 2

Comparative example 2

A reaction set-up as depicted by figure 3, otherwise similar to example 1 with the exceptions that two HDO reactors in series were used and that there was no gas removal after the first HDO reactor before entering the feed (306) into the second HDO reactor (302) downstream of the first HDO reactor (301). A catalyst bed similar to the polishing bed of figure 1 was installed inside the second HDO reactor (302). The liquid paraffinic effluent (306) from the first HDO reactor was directed directly to the second HDO reactor i.e. without removal of the gaseous by-products including nitrogen containing compounds after the first HDO reactor before entering the liquid paraffinic effluent into the second HDO reactor. The final liquid paraffinic effluent stream (312) obtained after the second HDO reactor (302) was directed to the stripper (314) for removal of the gaseous impurities, and subsequently into the isomerization reactor. The catalysts and reaction conditions were the same as for example 1 .

This reactor setup was similar to the prior art reactor setup described in US 2011/0094149 A1. As can be seen from table 6, the nitrogen content of all the runs (13-18) caused much higher nitrogen contents compared to the nitrogen contents in example 1 .

The set-up according to figure 3 was found to be able to reduce the lower amounts of nitrogen impurities, at lower amounts of nitrogen content in the initial feed, e.g. about 25 ppm of nitrogen or less. However, when the amount of nitrogen is increased to 150 wppm or higher in the fresh feed, the nitrogen remaining after the HDO and polishing was increased to a value of 0.8 ppm, or higher. The increase of nitrogen content in the isomerization resulted in poorer cold properties and yield for the aviation fuel component retrieved from the separation distillation after isomerization, a turbidity point of about -15 °C was obtained with aviation fuel yield of 10 wt-% in the run 18 where the nitrogen initial content was 1000 ppm.

Table 6 - two HDO reactors - fresh catalyst - Figure 3