WO2015026596A1 - Systèmes et procédés de production de carburant à partir d'une charge de départ renouvelable - Google Patents

Systèmes et procédés de production de carburant à partir d'une charge de départ renouvelable Download PDF

Info

Publication number
WO2015026596A1
WO2015026596A1 PCT/US2014/050855 US2014050855W WO2015026596A1 WO 2015026596 A1 WO2015026596 A1 WO 2015026596A1 US 2014050855 W US2014050855 W US 2014050855W WO 2015026596 A1 WO2015026596 A1 WO 2015026596A1
Authority
WO
WIPO (PCT)
Prior art keywords
reaction zone
aromatic compounds
aromatic
isomerization
renewable feedstock
Prior art date
Application number
PCT/US2014/050855
Other languages
English (en)
Inventor
Daniel ELLIG
Stanley Joseph Frey
Timothy A. Brandvold
Original Assignee
Uop Llc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Uop Llc filed Critical Uop Llc
Publication of WO2015026596A1 publication Critical patent/WO2015026596A1/fr

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G3/00—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
    • C10G3/50—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids in the presence of hydrogen, hydrogen donors or hydrogen generating compounds
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G3/00—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
    • C10G3/42—Catalytic treatment
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
    • C10G45/58—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to change the structural skeleton of some of the hydrocarbon content without cracking the other hydrocarbons present, e.g. lowering pour point; Selective hydrocracking of normal paraffins
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
    • C10G45/58—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to change the structural skeleton of some of the hydrocarbon content without cracking the other hydrocarbons present, e.g. lowering pour point; Selective hydrocracking of normal paraffins
    • C10G45/68—Aromatisation of hydrocarbon oil fractions
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G65/00—Treatment of hydrocarbon oils by two or more hydrotreatment processes only
    • C10G65/02—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only
    • C10G65/04—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only refining steps
    • C10G65/046—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only refining steps at least one step being an aromatisation step
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L1/00—Liquid carbonaceous fuels
    • C10L1/04—Liquid carbonaceous fuels essentially based on blends of hydrocarbons
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1011—Biomass
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/30—Aromatics
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P30/00—Technologies relating to oil refining and petrochemical industry
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P30/00—Technologies relating to oil refining and petrochemical industry
    • Y02P30/20—Technologies relating to oil refining and petrochemical industry using bio-feedstock

Definitions

  • the present disclosure generally relates to systems and methods for producing fuels from renewable feedstocks, and more particularly relates to systems and methods for converting renewable feedstocks into normal paraffins, isomerized paraffins and aromatic compounds useful for fuel.
  • renewable feedstocks include, but are not limited to, plant oils such as corn, rapeseed, canola, and soybean, animal fats such as tallow and fish oils, algal oils, and various waste streams such as yellow and grown greases and sewage sludge.
  • plant oils such as corn, rapeseed, canola, and soybean
  • animal fats such as tallow and fish oils, algal oils
  • waste streams such as yellow and grown greases and sewage sludge.
  • the common feature of these sources is that they are composed of glycerides and free fatty acids (FFA).
  • jet fuel which has a more narrow boiling range than diesel.
  • the boiling range for jet fuel is within the diesel boiling range, but limited towards the lower end of the boiling range.
  • Most jet fuels are made from compounds having 9 to 14 carbons, and most diesel fuels are made from compounds having 9 to 18 carbons.
  • Jet fuel produced from renewable sources is sometimes called green jet fuel, or just "green jet” for short.
  • Other terms used to describe jet fuel produced from renewable sources include hydroprocessed renewable jet (HRJ), or hydroprocessed esters and fatty acids (HEFA).
  • HRJ hydroprocessed renewable jet
  • HEFA hydroprocessed esters and fatty acids
  • There are some specific requirements for green jet that may not apply to jet fuel from petroleum crude oil feedstocks.
  • current ASTM standards call for the blending of green jet with petroleum based jet in order to meet a minimum concentration of 8 volume percent aromatics in the blended fuel.
  • the aromatic compounds may help swell gaskets in jet engines, which is thought to help prevent leaks.
  • Current production processes for green jet produce straight chain or branched paraffins, with very low concentrations of aromatic compounds.
  • Many specifications for jet fuel establish a maximum concentration for aromatic compounds, such as 25% by volume, so there is an upper limit to the amount of aromatics in green jet.
  • a system for producing fuel from a renewable feedstock.
  • the system includes a renewable feedstock feed system upstream from a deoxygenation reaction zone.
  • the deoxygenation reaction zone has a hydrogenation catalyst.
  • An aromatic production zone is downstream from the deoxygenation reaction zone, and includes an aromatic catalyst.
  • An isomerization reaction zone is also downstream from the deoxygenation reaction zone, and includes an isomerization catalyst.
  • a method for producing a fuel from a renewable feedstock is also provided.
  • the renewable feedstock is deoxygenated in a deoxygenation reaction zone to produce normal paraffins.
  • the normal paraffins are isomerized to form isomerized paraffins in an isomerization reaction zone.
  • Aromatic compounds are formed from non-aromatic compounds in an aromatic production zone downstream from the deoxygenation reaction zone.
  • a method for producing a fuel from a renewable feedstock.
  • the renewable feedstock is deoxygenated in a deoxygenation reaction zone to produce normal paraffins.
  • the cold flow properties of the normal paraffins are improved by forming aromatic compounds from the normal paraffins.
  • FIG. 1 is a schematic diagram of an exemplary embodiment of a renewable feedstock feed system.
  • FIG. 2 is a schematic diagram illustrating an exemplary embodiment of a system and method for converting a renewable feedstock into paraffinic and aromatic compounds useful as a fuel. Heat exchangers are shown as circles in the process lines.
  • FIGS. 3-5 are schematic diagrams illustrating different exemplary embodiments for preparing different types of hydrocarbon products produced from a renewable feedstock. Heat exchangers are shown as circles in the process lines.
  • FIGS. 6-9 are schematic diagrams showing various exemplary embodiments of a system and method for converting a renewable feedstock into paraffinic and aromatic compounds useful as a fuel. Heat exchangers are shown as circles in the process lines.
  • the various embodiments relate to systems and methods for producing a hydrocarbon stream useful as a diesel boiling range fuel, a jet fuel, or a fuel blending component.
  • the hydrocarbon stream is produced from renewable feedstocks such as bio renewable feedstocks originating from plants or animals.
  • the renewable feedstock is first deoxygenated to produce normal paraffins (n-paraffins).
  • the n-paraffins are isomerized to form isomerized paraffins, which are branched paraffins, to improve the cold flow properties of the product.
  • paraffins are converted to aromatic compounds, so the hydrocarbon stream can be used without blending, or with minimal blending.
  • the systems and methods are configured such that the aromatic compounds are not sent through the isomerization process, because most aromatics are converted to non-aromatic compounds in the isomerization process.
  • renewable feedstocks 10 are stored and delivered to the system and process described below from a renewable feedstock feed system 6.
  • the renewable feedstock feed system 6 includes a renewable feedstock storage tank 12, a renewable feedstock pump 14 for pumping the feedstock to the system, and associated piping.
  • Other embodiments of the renewable feedstock feed system 6 exist, such as a pipeline from a different source, and a pressurized renewable feedstock feed tank 12 without a renewable feedstock pump 14.
  • the renewable feedstock 10 is passed to the system and process described below in a renewable feedstock feed stream 8.
  • renewable feedstock 10 is meant to include feedstocks other than those derived from petroleum crude oil.
  • the renewable feedstocks as contemplated herein are any of those which include glycerides or free fatty acids (FFA). Most of the glycerides will be triglycerides, but monoglycerides and diglycerides may be present and processed as well.
  • renewable feedstocks examples include, but are not limited to, canola oil, corn oil, rapeseed oil, soybean oil, colza oil, tall oil, sunflower oil, hempseed oil, olive oil, linseed oil, coconut oil, castor oil, peanut oil, palm oil, mustard oil, camelina oil, penny cress oil, tallow, yellow and brown greases, lard, train oil, jatropha oil, fats in milk, fish oil, algal oil, sewage sludge, and the like.
  • Additional examples of renewable feedstocks 10 include non-edible vegetable oils, such as oils from Madhuca indica (mahua), Pongamia pinnata, and Azadirachta indica (neem).
  • the glycerides and FFAs of the typical vegetable or animal fat contain aliphatic hydrocarbon chains in their structure which have 8 to 24 carbon atoms.
  • the majority of the fats and oils contain high concentrations of fatty acids with 16 to 18 carbon atoms, and many types of oils contain aliphatic hydrocarbon chains within a limited range, such as 14 to 18. Only a limited number of oil types include aliphatic hydrocarbon chains with 8 carbon atoms or 24 carbon atoms, so the 8 to 24 carbon atoms range is meant to encompass mixtures of all types of oils.
  • Co-feeds, or mixtures of renewable feedstocks 10 and petroleum derived hydrocarbons may also be used as the feedstock.
  • feedstock components that may be used, especially as a co-feed component in combination with the above listed feedstocks, include spent motor oils and industrial lubricants; used paraffin waxes; liquid derived from the gasification of coal, biomass, or natural gas followed by a downstream liquefaction step such as Fischer-Tropsch technology; liquids derived from depolymerization (thermal or chemical) of waste plastics such as polypropylene, high density polyethylene, and low density polyethylene; and other synthetic oils generated as byproducts from petrochemical and chemical processes. Mixtures of the above feedstocks may also be used as co-feed components.
  • One advantage of using a co-feed component is the transformation of what may have been a waste product into a valuable co-feed component to the current process.
  • a sulfiding agent 24 can be added to the renewable feedstock 10.
  • Several reactors described more fully below use catalysts of various types, and these catalysts are used in a sulfide state. Sulfur is added to the process to maintain the catalysts in the sulfided state.
  • the sulfur is added using a sulfiding agent feed system 23 configured to add a sulfiding agent 24 to the renewable feedstock feed stream 8, which is upstream from the reaction zones described below.
  • the sulfiding agent feed system includes a sulfiding agent tank 26 and a sulfiding agent pump 28, but other embodiments are also possible.
  • the sulfur is measured as elemental sulfur, regardless of the compound containing the sulfur.
  • Sulfur can be added in many forms.
  • suitable sulfiding agents 24 include, but are not limited to, dimethyl disulfide, dibutyl disulfide, and hydrogen sulfide.
  • the sulfur may be obtained from various sources, such as part of a hydrogen stream from a hydrocracking unit or hydro treating unit, or sulfur compounds removed from kerosene or diesel, and disulfide oils removed from sweetening units such as Merox® units.
  • a hydrogenation catalyst is described more fully below, and sulfur concentrations of less than 2,000 ppm are typically sufficient to maintain the hydrogenation catalyst and the other catalysts described below in a sulfide state.
  • sulfiding agent 24 to the renewable feedstock feed stream 8
  • some renewable feedstocks 10 contain sufficient sulfur to maintain the catalysts in a sulfided state.
  • Sulfur can also be added to the renewable feedstock storage tank 12, the reactors containing the catalysts, or a wide variety of other locations.
  • the renewable feedstock feed stream 8 passes to a pretreatment zone 16.
  • Many renewable feedstocks 10 that can be used herein contain a variety of impurities.
  • tall oil is a byproduct of the wood processing industry, and includes esters and rosin acids in addition to FFAs. Rosin acids are cyclic carboxylic acids.
  • the renewable feedstocks 10 may also contain contaminants such as alkali metals, (e.g. sodium and potassium), phosphorous, various solids, water, and detergents.
  • the renewable feedstock 10 may be pre-cleaned (not shown) prior to introduction into the processes illustrated in FIG. 2, where several different types of pre-cleaning are possible.
  • the renewable feedstock 10 can be subjected to a mild acid wash by contact with dilute sulfuric, nitric, or hydrochloric acid in a reactor.
  • the acid wash can be a continuous process or a batch process, and the dilute acid contact can be at ambient temperature and atmospheric pressure.
  • Other possible pre-cleaning steps include, but are not limited to, contacting the renewable feedstock 10 with an ion exchange resin such as Amberlyst®-15, subjecting the renewable feedstock 10 to a caustic treatment, bleaching the renewable feedstock 10 with an adsorbent, filtration, solvent extraction, hydro processing, or combinations of the above.
  • a recycle hydrogen stream 95 (described more fully below) is added to the renewable feedstock feed stream 8 and flows downstream to the pretreatment zone 16.
  • upstream and downstream means two process units or components are fluidly coupled together, and at least a portion of the fluid from one of the process units or components flows to the other process unit or component.
  • a portion of a hot separator bottoms stream 34 (described more fully below) is also added to the renewable feedstock feed stream 8 before entry into the pretreatment zone 16.
  • One possible pretreatment step in the pretreatment zone 16 involves metals removal by contacting the renewable feedstock feed stream 8 with a guard bed catalyst in the pretreatment zone 16 at pretreatment conditions.
  • the guard bed catalyst is alumina, either with or without demetallation catalysts such as nickel or cobalt.
  • the conditions at which the reactor containing the guard bed catalyst is operated are well known in the art, and include a temperature from 40 °C to 400 °C, for example from 150 °C to 300 °C.
  • Operating pressures for the guard bed catalyst are from 690 kilopascals (kPa) absolute (100 pounds per square inch absolute (psia)) to 13,800 kPa absolute (2,000 psia), for example from 1,380 kPa absolute (200 psia) to 6,900 kPa absolute (1,000 psia).
  • a portion of the hot separator bottoms stream 34 may be added at various locations in the pretreatment zone to aid in temperature control, hydrogen solubility, or other purposes, but in other embodiments different streams are added or no streams are added at side locations in the pretreatment zone 16.
  • a pretreatment effluent 18 flows downstream to a deoxygenation reaction zone 20 including one or more catalyst beds in one or more reactors.
  • the guard bed catalyst in the pretreatment zone 16 initiates the deoxygenation of the renewable feedstock feed stream 8 to some degree.
  • the pretreatment effluent 18 is contacted with a hydrogenation catalyst 22 (sometimes referred to as a hydrotreating catalyst) in the presence of hydrogen at hydrogenation conditions.
  • the hydrogen for this reaction is provided from the recycle hydrogen stream 95 added to the renewable feedstock feed stream 8. Under these conditions, the olefmic or unsaturated portions of n- paraffmic chains are hydrogenated.
  • Hydrogenation catalysts 22 are any of those well known in the art such as nickel or nickel/molybdenum dispersed on a high surface area support.
  • Other hydrogenation catalysts 22 include one or more noble metal catalytic elements dispersed on a high surface area support. Non-limiting examples of noble metals include Pt and/or Pd.
  • Hydrogenation conditions include a temperature of 40° centigrade (C) to 400° C, and a pressure of 690 kilopascals (kPa) absolute (100 psia) to 13,800 kPa absolute (2,000 psia). In another embodiment the hydrogenation conditions include a temperature of 200° C to 300° C, and a pressure of 1,380 kPa absolute (200 psia) to 6,900 kPa absolute (1,000 psia). Other operating conditions for the deoxygenation reaction zone 20 can also be used.
  • the hydrogenation catalysts 22 discussed above are also capable of catalyzing decarboxylation, decarbonylation and/or hydrodeoxygenation of the renewable feedstock 10 to remove oxygen.
  • Decarboxylation, decarbonylation, and hydrodeoxygenation are herein collectively referred to as "deoxygenation reactions", and the deoxygenation reactions and the olefin hydrogenation reactions simultaneously occur in the deoxygenation reaction zone 20.
  • Decarboxylation conditions include a relatively low pressure of 3,450 kPa (500 psia) to 6,900 kPa (1,000 psia), a temperature of 200° C to 400° C, and a liquid hourly space velocity of 0.5 to 10 hr 1 .
  • the decarboxylation conditions include the same relatively low pressure of 3,450 kPa (500 psia) to 6,900 kPa (1,000 psia), a temperature of 288° C to 345° C, and a liquid hourly space velocity of 1 to 4 hr "1 .
  • Hydrogenation is an exothermic reaction, so the temperature in the deoxygenation reaction zone 20 increases as the renewable feedstock feed stream 8 passes through. Decarboxylation and hydrodeoxygenation reactions begin to occur as the temperature increases. The rate of the deoxygenation reactions increases from the front of the bed to the back of the bed as the temperature increases.
  • the deoxygenation reaction zone 20 can include one or more reactors in series, and can also include parallel reactors or sets of reactors.
  • the hydrodeoxygenation reaction consumes hydrogen and produces water as a byproduct, while the decarbonylation and decarboxylation reactions produce carbon monoxide (CO) or carbon dioxide (C0 2 ) without consuming hydrogen.
  • the product from the deoxygenation reactions includes a liquid portion and a gaseous portion.
  • the liquid portion includes a hydrocarbon fraction that is largely n-paraffin compounds having a high cetane number.
  • the gaseous portion includes hydrogen, carbon dioxide (C0 2 ), carbon monoxide (CO), water vapor, propane, and perhaps sulfur components such as hydrogen sulfide. It is possible to separate and collect the liquid (n-paraffin compound) portion as a diesel fuel product without further reactions.
  • n-paraffins can be isomerized to produce isomerized paraffins, which improves the cold flow properties of the fuel.
  • the cold flow properties can also be improved by adding aromatic compounds with an average boiling point lower than the n-paraffin average boiling point.
  • the isomerized paraffins are branched, and both n-paraffins and branched paraffins are non-aromatic compounds.
  • aromatic compounds are desired in the fuel product. There is often an upper specification on aromatics, such as 25% by volume for Jet A, so only a partial conversion of paraffins to aromatics is desired. Paraffins, including normal and/or isomerized paraffins, are partially converted to aromatic compounds in an aromatics reaction zone 60, which can be placed in a variety of locations in the process flow.
  • the embodiment shown in FIG. 2 depicts the aromatics reaction zone 60 as a catalyst bed in the same reactor as the deoxygenation reaction zone 20, where the aromatics reaction zone 60 is downstream from the deoxygenation reaction zone 20.
  • the aromatics reaction zone 60 could also be in a separate reactor directly downstream from the deoxygenation reaction zone 20, and many other locations are possible in various embodiments.
  • the aromatics reaction zone 60 includes an aromatic catalyst 62 that converts paraffins, which are non-aromatic compounds, into aromatic compounds.
  • the aromatic catalyst 62 will form aromatic compounds from either n-paraffins or branched paraffins, so the aromatic production zone 60 can be either upstream or downstream from the isomerization reaction zone 40 (described below) in various embodiments.
  • the aromatic production zone 60 should be downstream from the deoxygenation reaction zone 20, so the feed to the aromatic production zone 60 is paraffmic hydrocarbons.
  • a portion of the hot separator bottoms stream 34 is added at various locations to the aromatics reaction zone 60, but different side feeds or no side feed are added in other embodiments.
  • the hot separator bottoms stream 34 can aid in temperature control and hydrogen solubility, among other purposes.
  • Aromatic production zone conditions include a temperature of 300° C to 450° C and a pressure of 100 kPa absolute (15 psia) to 4,140 kPa absolute (600 psia).
  • aromatic reaction conditions are also possible, as known in the art.
  • Several different types of aromatic catalysts 62 can be used. For example, nickel and tungsten deposited on a silica alumina substrate is effective, but other metals and other substrates can also be used. Some examples of other possible catalysts include aluminum chloride, platinum, platinum and tin, platinum and rhenium, and others.
  • a wide variety of catalyst substrates can also be used, including but not limited to zeolites, silica alumina, amorphous alumina, etc.
  • excess sulfur from the deoxygenation reaction zone 20 maintains the aromatic catalyst 62 is a sulfided state. In other embodiments, the aromatic catalyst 62 is not sulfided.
  • the aromatic production zone effluent 64 passes to an optional hot separator 30, so the hot separator 30 is downstream from the aromatic production zone 60.
  • the hot separator 30 is also downstream from the deoxygenation reaction zone 20 in many embodiments.
  • One purpose of the hot separator 30 is to separate at least some of the gaseous portion from the deoxygenation reaction zone 20 from the liquid portion. The entire gaseous portion from the deoxygenation reaction zone 20 is fed to the aromatic production zone 60 in the embodiment shown in FIG. 2.
  • the separated hydrogen is recycled back to the deoxygenation reaction zone 20 in some embodiments, as described more fully below.
  • water, CO, C0 2 , and any ammonia or hydrogen sulfide are selectively stripped in the hot separator 30 using hydrogen.
  • additional hydrogen is used as the stripping gas, but other gases could also be used.
  • the temperature is controlled to achieve the desired separation, and the pressure can be maintained at the same pressure as the deoxygenation reaction zone 20 and the isomerization reaction zone 40 to minimize both investment and operation costs.
  • the hot separator 30 may be operated at conditions ranging from a pressure of 690 kPa absolute (100 psia) to 13,800 kPa absolute (2,000 psia), and a temperature of 40° C to 350° C. In another embodiment, the hot separator 30 may be operated at conditions ranging from a pressure of 1,380 kPa absolute (200 psia) to 6,900 kPa absolute (1,000 psia), or 2,410 kPa absolute (350 psia) to 4,880 kPa absolute (650 psia), and a temperature of 50° C to 350° C.
  • the paraffinic components of the hot separator bottoms stream 34 are primarily n-paraffins which range from 8 to 24 carbon atoms depending on the type of renewable feedstock 10 used, and the aromatic components (if present) are either comparable in size or smaller. Different renewable feedstocks 10 will result in different distributions of paraffins.
  • the hot separator bottoms stream 34 is divided and transferred to various locations in different embodiments. A portion of the hot separator bottoms stream 34 may be recycled and added to the pretreatment zone 16, the deoxygenation reaction zone 20, and the aromatic production zone 60, at various locations, as described above. The recycled hot separator bottoms stream 34 can help control the temperature and/or the hydrogen solubility in the various reaction zones.
  • the hot separator bottoms stream 34 primarily includes n-paraffins (from the deoxygenation reaction zone 20) and aromatic compounds (from the aromatic production zone 60).
  • the aromatic compounds are separated from the n-paraffins and diverted around the isomerization reaction zone 40 described below, as the isomerization reaction zone converts aromatic compounds into non-aromatic compounds.
  • the aromatic compounds have a lower boiling point than the n-paraffins, so distillation can be used for the separation.
  • the molecular weight of the aromatic compounds and the non-aromatic compounds are the same, and thus the boiling points are the same.
  • liquid/liquid extraction systems with an extraction solvent, such as sulfolane, can be used.
  • the aromatic production zone 60 operating conditions can be modified to produce smaller aromatic compounds from soybean oil or other renewable feedstocks 10, such as higher temperatures, more active catalysts, removal of water, CO, and C0 2 before the aromatic catalyst, etc.
  • the lower the molecular weight for either paraffins or aromatic compounds the lower the boiling point. Smaller aromatic compounds help improve cold flow properties of the fuel, and can be separated from the higher molecular weight paraffins by a relatively simple distillation step.
  • the aromatics reaction zone 60 can be positioned upstream from the isomerization reaction zone 40, so the aromatic compounds in the aromatic production zone effluent 64 flow to the aromatic distillation column 70 by way of the hot separator bottoms stream 34.
  • the aromatics distillation column 70 has an aromatics distillation column bottoms stream 71 with heavy components. Many of the n-paraffins from the deoxygenation reaction zone 20 are not converted to smaller aromatic compounds, and these are transferred to the isomerization reaction zone 40 from the aromatics distillation column bottoms stream 71. Any large aromatic compounds with the same number of carbon atoms as the paraffinic compounds will also be in the aromatics distillation column bottoms stream 71.
  • the aromatics distillation column 70 is upstream from the isomerization reaction zone 40, and the aromatic distillation column bottoms stream 71 is fed to the isomerization reaction zone 40.
  • the aromatic distillation column bottoms stream 71 is combined with a hydrogen feed line 36 in some embodiments, where the hydrogen feed line 36 introduces fresh hydrogen for the isomerization reaction.
  • a fresh hydrogen compressor 98 helps urges the fresh hydrogen into the process.
  • aromatics distillation column side stream 73 Smaller, lighter aromatic compounds are removed in an aromatics distillation column side stream 73, and these aromatic compounds are diverted around the isomerization reaction zone 40.
  • the aromatics distillation column side stream 73 serves as an aromatic compounds stream, but in other embodiments the aromatic compounds are removed in an aromatic distillation column overhead 75 with other light compounds. Therefore, the aromatic distillation column overhead 75 is the aromatic compounds stream in some embodiments.
  • the aromatic compounds stream is directed to the aromatics storage tank 72, but the aromatic compounds can be diverted around the isomerization reaction zone 40 in other manners, such as direct piping.
  • the aromatic compounds in the aromatic storage tank 72 are added to the hydrocarbons downstream from the isomerization reaction zone 40, as shown more fully below.
  • the aromatic distillation column bottoms stream 71 primarily contains n- paraffms, and may contain some large aromatic compounds in some embodiments, and could be used as a diesel boiling range fuel. However, the cold flow properties can be improved by isomerizing at least some of the n-paraffins in the isomerization reaction zone 40.
  • the isomerization reaction zone 40 contains an isomerization catalyst 42, and the aromatic distillation column bottoms stream 71 are contacted with the isomerization catalyst 42 under isomerization conditions to at least partially isomerize the n-paraffins to branched paraffins.
  • the isomerization reaction zone 40 is downstream from the hot separator 30, and in some embodiments the isomerization reaction zone 40 is also downstream from the aromatic distillation column 70.
  • a jet fractionator bottoms stream 90 can also be added to the aromatic distillation column bottoms stream 71 upstream from the isomerization reaction zone 40.
  • the jet fractionator bottoms stream 90 includes hydrocarbons that are too heavy, with too high a boiling point, to be useful as a jet fuel. These larger molecules may be cracked into smaller molecules in the isomerization reaction zone 40 to improve the jet fuel yield. The larger molecules can also aid the isomerization reaction zone 40 in other ways, such as temperature control and hydrogen solubility.
  • the isomerization reaction zone effluent 41 is a branched-paraffin-rich stream.
  • rich it is meant that the isomerization reaction zone effluent 41 has a greater concentration of branched paraffins than the stream entering the isomerization reaction zone 40, which is the aromatics distillation column bottoms stream 71 in the embodiment shown in FIG. 2, and preferably includes greater than 50 mass percent branched paraffins. It is envisioned that the isomerization reaction zone effluent 41 may contain 70, 80, or 90 mass percent branched paraffins.
  • the isomerization reaction zone 40 also converts most aromatic compounds to non-aromatic compounds, so if aromatic compounds are desired in the final product they should not be processed in the isomerization reaction zone 40.
  • Isomerization can be carried out in a separate bed of the same reactor used in the deoxygenation reaction zone 20, or the isomerization can be carried out in a separate reactor.
  • a second reactor is employed for the isomerization reaction zone 40.
  • the aromatic column distillation bottoms stream 71 is contacted with the isomerization catalyst 42 in the presence of hydrogen at isomerization conditions to isomerize the n-paraffms to branched paraffins. Only minimal branching is required to overcome the poor cold- flow characteristics of the n-paraffms.
  • the predominant isomerized paraffin product is a mono-branched hydrocarbon, because process conditions that produce significant branching also increase the risk of undesired cracking. Undesired cracking produces smaller compounds that are not useful as a jet fuel or a diesel fuel, and therefore reduce the overall yield.
  • the isomerization of the n-paraffms can be accomplished by using a variety of suitable catalysts.
  • the isomerization reaction zone 40 includes one or more beds of isomerization catalyst 42, and the catalyst beds can be in series and/or parallel.
  • a single reactor may include one or more catalyst beds, so the isomerization reaction zone 40 can also include one or more reactors.
  • the isomerization reaction zone is operated in a co-current mode of operation. Fixed bed trickle down flow or fixed bed liquid upward flow modes are both suitable. Remaining sulfur compounds maintain the isomerization catalyst 42 is a sulfided state.
  • Suitable isomerization catalysts 42 include a metal of Group VIII (IUPAC 8-10) of the Periodic Table and a support material. Suitable Group VIII metals include platinum and palladium, each of which may be used alone or in combination.
  • the support material may be amorphous or crystalline, and many different support materials can be used. Suitable support materials include, but are not limited to, amorphous alumina, amorphous silica-alumina, ferrierite, metal aluminumsilicophosphates, laumontite, cancrinite, offretite, the hydrogen form of stillbite, the magnesium or calcium form of mordenite, and the magnesium or calcium form of partheite, each of which may be used alone or in combination.
  • the isomerization catalyst 42 may also include one or more modifiers, such as those selected from the group of lanthanum, cerium, praseodymium, neodymium, samarium, gadolinium, terbium, and mixtures thereof.
  • the isomerization reaction occurs when hydrocarbons pass through the isomerization catalyst 42 at isomerization conditions.
  • Isomerization conditions include a temperature of 150° C to 360° C and a pressure of 1,720 kPa absolute (250 psia) to 4,720 kPa absolute (700 psia).
  • the isomerization conditions include a temperature of 300° C to 360° C and a pressure of 3,100 kPa absolute (450 psia) to 3,800 kPa absolute (550 psia).
  • Other operating conditions for the isomerization reaction zone 40 can also be used.
  • the isomerization reaction zone effluent 41 is processed through one or more separation steps to obtain a hydrocarbon stream useful as a fuel, such as jet fuel or diesel fuel.
  • the isomerization reaction zone effluent 41 includes both a liquid component and a gaseous component, various portions of which can be recycled, so multiple separation steps may be employed.
  • the isomerization reaction zone effluent 41 is separated in an isomerization effluent separator 44 positioned downstream from the isomerization reaction zone 40. In the embodiment shown in FIG. 2, the isomerization effluent separator 44 is optional.
  • Hydrogen exits the isomerization effluent separator 44 in the isomerization effluent separator overhead stream 46, and the liquid portion exits in the isomerization effluent separator bottoms stream 48.
  • the isomerization effluent separator overhead stream 46 is fed to the aromatics distillation column 70 in some embodiments, and the gaseous portions flow into the aromatics distillation column overhead stream 75.
  • Suitable operating conditions of the isomerization effluent separator 44 include, for example, a temperature of 230° C and a pressure of 4,100 kPa absolute (600 psia), but other operating conditions are also possible. If there is a low concentration of carbon oxides, or the carbon oxides are removed, the hydrogen may be directly recycled and re- used in the process. The hydrogen is a reactant in the oxygenation reaction zone 20 and the isomerization reaction zone 40, and different renewable feedstocks 10 will consume different amounts of hydrogen. The isomerization effluent separator 44 allows flexibility for the process to operate even when larger amounts of hydrogen are consumed in the deoxygenation reaction zone 20. Furthermore, at least a portion of the isomerization effluent separator bottoms stream 48 can be recycled to the isomerization reaction zone 40 (not shown) to increase the degree of isomerization, to aid in temperature control, or for other purposes.
  • the remainder of the isomerization effluent separator bottoms stream 48 still has liquid and gaseous components and can be cooled by various techniques, such as air cooling or water cooling. After cooling, the isomerization effluent separator bottoms stream 48 is passed to a cold separator 50 where the liquid component is separated from the gaseous component.
  • the hot separator overhead stream 32 and the aromatic distillation column overhead stream 75 can be combined with the isomerization effluent separator bottoms stream 48 upstream from the cold separator 50.
  • Suitable operating conditions of the cold separator 50 include, for example, a temperature of 20° C to 60° C and a pressure of 3,850 kPa absolute (560 psia).
  • a water byproduct stream is also separated in the cold separator 50 (not shown).
  • a cold separator overhead stream 52 is mostly hydrogen and the carbon dioxide from the decarboxylation reaction.
  • Other components such as CO, propane, and hydrogen sulfide or other sulfur containing components may be present as well.
  • Water, CO, and C0 2 can negatively impact the catalyst performance in the isomerization reaction zone 40. It is desirable to recycle the hydrogen, but if the C0 2 and other components are not removed, their concentrations can build up and effect the operation of the isomerization reaction zone 40.
  • a recovery gas cleaner 74 can be used to increase the purity of the cold separator overhead stream 52.
  • the carbon dioxide can be removed from the hydrogen by several different processes, including but not limited to absorption with an amine, reaction with a hot carbonate solution, pressure swing absorption, etc. If desired, essentially pure carbon dioxide can be recovered by regenerating the spent absorption media.
  • a sulfur containing component such as hydrogen sulfide, may also be present. The sulfur containing component is used to help control the relative amounts of the decarboxylation reaction and the hydrogenation reaction in the deoxygenation reaction zone 20. The amount of sulfur is generally controlled, so the sulfur is also removed before the hydrogen is recycled.
  • Various methods can be used, such as absorption with an amine or a caustic wash, and the carbon dioxide and sulfur containing components (as well as other components) are removed in a single separation step in some embodiments.
  • the recycle hydrogen stream 95 exits the recovery gas cleaner 74 after the impurities have been removed.
  • a recycle hydrogen compressor 96 urges the hydrogen back into the process. As discussed above, the recycle hydrogen stream 95 is combined with the renewable feedstock feed stream 8 and feeds the pretreatment zone 16.
  • the cold separator bottoms stream 54 or the liquid component separated in the cold separator 50, contains the hydrocarbons useful as jet fuel or diesel boiling range fuel, as well as smaller amounts of naphtha 100 and liquid propane gas (LPG) 102.
  • the cold separator bottoms stream 54 may be recovered as diesel boiling range fuel or it may be further purified in a product stripper 76 which separates lower boiling components and dissolved gases from the diesel boiling range hydrocarbons.
  • the product stripper 76 can be operated, for example, with a vapor temperature of from 20° C to 200° C and a pressure from 0 kPa (0 psia) to 1,380 kPa absolute (200 psia) at the overhead of the product stripper 76.
  • the product stripper 76 produces a product stripper overhead stream 78 and a product stripper bottoms stream 80.
  • the product stripper overhead stream 78 includes the LPG 102, naphtha 100, and light hydrocarbons present in a lean gas 104.
  • the lean gas 104 is separated from the LPG 102 and naphtha 100 in a light gas separator 106 as a gas in a light gas separator overheads stream 108.
  • a light gas separator bottoms stream 110 from the light gas separator 106 includes the liquid LPG 102 and naphtha 100.
  • the LPG 102 and naphtha 100 may be further separated in a debutanizer 82 (also called a depropanizer) that produces the LPG 102 as an overhead stream and the naphtha 100 as a bottoms stream.
  • the debutanizer 82 can be operated, for example, at a vapor temperature of 20° C to 200° C and a pressure from 0 to 2,760 kPa absolute (0 to 400 psia) at the debutanizer overhead, but other conditions are also possible.
  • the LPG 102 may be sold as a valuable product, used as a fuel gas, or used in other processes such as the feed to a hydrogen production facility, a co-feed to a reforming process, or used as a fuel blending component.
  • the product stripper bottoms stream 80 is fed to a jet fractionator 84 to separate jet fuel from higher boiling range diesel fuel compounds.
  • the jet fractionator 84 is an optional component used when jet fuel 92 is desired.
  • the jet fractionator 84 produces a jet fractionator overhead stream 86, a jet fractionator side stream 88, and a jet fractionator bottoms stream 90.
  • the jet fractionator overhead stream 86 include some light naphtha compounds that are combined with the debutanizer bottoms stream 114 in some embodiments.
  • the jet fractionator side stream 88 contains the jet fuel 92, and heavier compounds exit in the jet fractionator bottoms stream 90.
  • kerosene is stripped from the jet fuel 92 after separation (not shown).
  • the jet fractionator bottoms stream 90 has too high a boiling point to use as a jet fuel.
  • the jet fractionator bottoms stream 90 can be used in alternative ways, such as recycling into the isomerization reaction zone 40, direct use or blending for diesel fuel, or combined with the feed to the isomerization reaction zone 40.
  • the aromatic compounds from the aromatic storage tank 72 can be added back to the fuel at several different locations downstream from the isomerization reaction zone 40.
  • the embodiment shown in FIG. 3 illustrates the aromatic compounds added to the jet fractionator side stream 88.
  • the aromatic compounds are added to the product stripper bottoms stream 80.
  • the aromatic compounds are added back to the cold separator bottoms stream 54.
  • the aromatic compounds are added to other locations downstream from the isomerization reaction zone 40.
  • the aromatic compounds are added to the hydrocarbons downstream from the isomerization reaction zone 40 without the use of an aromatic storage tank 72.
  • FIG. 6 illustrates another embodiment where the aromatics reaction zone 60 is directly downstream from the deoxygenation reaction zone 20, so a deoxygenation reaction zone effluent 21 serves as the feed to the aromatics reaction zone 60.
  • FIG. 6 shows separate reactors for the aromatics reaction zone 60 and the deoxygenation reaction 20, but one reactor could also be used as illustrated in FIG. 2.
  • the embodiment illustrated in FIG. 6 also shows the hot separator bottoms stream 34 feeding only the aromatics distillation column 70.
  • FIG. 7 illustrates another embodiment, where the aromatic production zone 60 and the aromatic distillation column 70 are positioned downstream from the hot separator 30 and upstream from the isomerization reaction zone 40.
  • the deoxygenation reaction zone effluent 21 feeds the hot separator 30 because the aromatics reaction zone 60 is downstream from the hot separator 30.
  • This embodiment also includes an enhanced hot separator 38 downstream from the hot separator 30, where the isomerization effluent separator overhead stream 46 is fed into the enhanced hot separator 38.
  • An enhanced hot separator overhead stream 37 is combined with the hot separator overhead stream 32, and then flows to the cold separator 50 to recover the gases.
  • An enhanced hot separator bottoms stream 39 flows from the enhanced hot separator 38 downstream to a pre-aromatics hydrogen separator 94, and the hydrogen feed line 36 and the jet fractionator bottoms stream 90 are added to the enhanced hot separator bottoms stream 39 before the pre-aromatics hydrogen separator 94.
  • Excess hydrogen is separated in the pre-aromatics hydrogen separator 94 and fed to the isomerization reaction zone 40 from a pre-aromatics separator overhead stream 91.
  • the pre-aromatics separator overhead stream 91 by-passes the aromatics reaction zone 60, so the isomerization reaction zone 40 is the first reaction zone for most of the fresh hydrogen from the hydrogen feed line 36.
  • a pre-aromatics separator bottoms stream 93 feeds the liquid components to the aromatics reaction zone 60.
  • the aromatics reaction zone 60 is downstream from the hot separator 30, so the deoxygenation reaction zone effluent 21 feeds the hot separator 30, and the hot separator bottoms stream 34 feeds the aromatics reaction zone 60.
  • the aromatics distillation column 70 is fed by the aromatics reaction zone effluent 64, and the isomerization effluent separator overhead stream 46 is also fed to the aromatics distillation column 70.
  • the aromatics distillation column bottoms stream 71 serves as the feed to the isomerization reaction zone 40, after the hydrogen feed line 36 and the jet fractionator bottoms stream 90 are added to it.
  • FIG. 9 illustrates yet another embodiment where the aromatics reaction zone 60 is downstream from the isomerization reaction zone 40.
  • the aromatic compounds are produced downstream from the isomerization reaction zone 40, so the aromatic compounds do not have to be separated to be diverted around the isomerization reaction zone 40. Therefore, the aromatics distillation column 70 is optional in this embodiment, but can be used to better control and measure the quantity of aromatics in the fuel product.
  • the quantity of aromatics produced in the aromatic production zone 60 can be controlled by adjusting the operating conditions within the aromatic production zone 60, such as the amount of aromatic catalyst 62, flow rates, temperatures, etc.
  • An enhanced hot separator 38 is illustrated in this embodiment, and the aromatic distillation column bottoms stream 71 feeds the isomerization effluent separator 44.
  • a first embodiment of the invention is a system for producing fuel from a renewable feedstock comprising a renewable feedstock feed system; a deoxygenation reaction zone comprising a hydrogenation catalyst, wherein the deoxygenation reaction zone is downstream from the renewable feedstock feed system; an aromatic production zone comprising an aromatic catalyst, wherein the aromatic production zone is downstream from the deoxygenation reaction zone; and an isomerization reaction zone comprising an isomerization catalyst, wherein the isomerization reaction zone is downstream from the deoxygenation reaction zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph further comprising an aromatics distillation column configured to produce an aromatics distillation column bottoms stream, wherein the aromatics distillation column is downstream from the aromatic production zone, and wherein the system is configured so that the aromatics distillation column bottoms stream flows to the isomerization reaction zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph wherein the aromatics distillation column is configured to produce an aromatic compounds stream, and wherein the system is configured such that the aromatic compounds stream bypasses the isomerization reaction zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph further comprising a hot liquid separator positioned downstream from the deoxygenation reaction zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph wherein the aromatic production zone is downstream from the isomerization reaction zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph further comprising an aromatics distillation column positioned downstream from the aromatic production zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph further comprising a pretreatment zone downstream from the renewable feedstock feed system and upstream from the deoxygenation reaction zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph further comprising a sulfiding agent feed system configured to add a sulfiding agent to the renewable feedstock prior to the deoxygenation reaction zone.
  • a second embodiment of the invention is a method of producing fuel from a renewable feedstock, the method comprising the steps of deoxygenating the renewable feedstock in a deoxygenation reaction zone to produce normal paraffins; isomerizing the normal paraffins in an isomerization reaction zone to produce isomerized paraffins; forming aromatic compounds from non-aromatic compounds in an aromatic production zone, and wherein the aromatic production zone is downstream from the deoxygenation reaction zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph further comprising separating the aromatic compounds from the non-aromatic compounds downstream from the aromatic production zone; feeding the non-aromatic compounds from the aromatic production zone into the isomerization reaction zone; and combining the aromatic compounds with the isomerized paraffins downstream from the isomerization reaction zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph wherein the step of deoxygenating the renewable feedstock further comprises deoxygenating the renewable feedstock with a hydrogenation catalyst, the method further comprising sulfiding the hydrogenation catalyst.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph wherein forming aromatic compounds from non-aromatic compounds further comprises forming aromatic compounds from non-aromatic compounds downstream from the isomerization reaction zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph wherein forming aromatic compounds from non-aromatic compounds further comprises forming aromatic compounds from non-aromatic compounds upstream from the isomerization reaction zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph further comprising removing gases from the non-aromatic compounds prior to forming the aromatic compounds.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph further comprising removing contaminants from the renewable feedstock in a pretreatment zone prior to deoxygenating the renewable feedstock.
  • a third embodiment of the invention is a method of producing fuel from a renewable feedstock, the method comprising the steps of deoxygenating the renewable feedstock in a deoxygenation reaction zone to produce normal paraffins; improving a cold flow property of the normal paraffins by forming aromatic compounds from normal paraffins.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the third embodiment in this paragraph wherein improving cold flow properties further comprises forming isomerized paraffins from the normal paraffins in an isomerization reaction zone downstream from the deoxygenation reaction zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the third embodiment in this paragraph further comprising diverting the aromatic compounds around the isomerization reaction zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the third embodiment in this paragraph further comprising sulfiding the hydrogenation catalyst.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the third embodiment in this paragraph further comprising removing contaminants from the renewable feedstock in a pretreatment zone prior to deoxygenating the renewable feedstock.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Crystallography & Structural Chemistry (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)

Abstract

L'invention concerne des procédés et des systèmes de production d'un carburant à partir d'une charge de départ renouvelable. Le procédé inclut la désoxygénation de la charge de départ renouvelable à l'aide d'un catalyseur d'hydrogénation dans une zone réactionnelle de désoxygénation pour produire des paraffines normales. Les paraffines normales sont isomérisées pour former des paraffines isomérisées en utilisant un catalyseur d'isomérisation dans une zone réactionnelle d'isomérisation. Les composés aromatiques sont formés à partir de composés non aromatiques à l'aide d'un catalyseur aromatique dans une zone de production aromatique en aval de la zone réactionnelle de désoxygénation.
PCT/US2014/050855 2013-08-23 2014-08-13 Systèmes et procédés de production de carburant à partir d'une charge de départ renouvelable WO2015026596A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US13/975,096 2013-08-23
US13/975,096 US20150057477A1 (en) 2013-08-23 2013-08-23 Systems and methods for producing fuel from a renewable feedstock

Publications (1)

Publication Number Publication Date
WO2015026596A1 true WO2015026596A1 (fr) 2015-02-26

Family

ID=52480948

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2014/050855 WO2015026596A1 (fr) 2013-08-23 2014-08-13 Systèmes et procédés de production de carburant à partir d'une charge de départ renouvelable

Country Status (2)

Country Link
US (1) US20150057477A1 (fr)
WO (1) WO2015026596A1 (fr)

Families Citing this family (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10968403B2 (en) * 2017-01-12 2021-04-06 Marathon Petroleum Company Lp Hydrocracker activity management
US10696906B2 (en) 2017-09-29 2020-06-30 Marathon Petroleum Company Lp Tower bottoms coke catching device
US10240096B1 (en) * 2017-10-25 2019-03-26 Saudi Arabian Oil Company Integrated process for activating hydroprocessing catalysts with in-situ produced sulfides and disulphides
US12000720B2 (en) 2018-09-10 2024-06-04 Marathon Petroleum Company Lp Product inventory monitoring
US12031676B2 (en) 2019-03-25 2024-07-09 Marathon Petroleum Company Lp Insulation securement system and associated methods
US11975316B2 (en) 2019-05-09 2024-05-07 Marathon Petroleum Company Lp Methods and reforming systems for re-dispersing platinum on reforming catalyst
US11124714B2 (en) 2020-02-19 2021-09-21 Marathon Petroleum Company Lp Low sulfur fuel oil blends for stability enhancement and associated methods
US20220268694A1 (en) 2021-02-25 2022-08-25 Marathon Petroleum Company Lp Methods and assemblies for determining and using standardized spectral responses for calibration of spectroscopic analyzers
US11702600B2 (en) 2021-02-25 2023-07-18 Marathon Petroleum Company Lp Assemblies and methods for enhancing fluid catalytic cracking (FCC) processes during the FCC process using spectroscopic analyzers
US11905468B2 (en) 2021-02-25 2024-02-20 Marathon Petroleum Company Lp Assemblies and methods for enhancing control of fluid catalytic cracking (FCC) processes using spectroscopic analyzers
US11898109B2 (en) 2021-02-25 2024-02-13 Marathon Petroleum Company Lp Assemblies and methods for enhancing control of hydrotreating and fluid catalytic cracking (FCC) processes using spectroscopic analyzers
US11692141B2 (en) 2021-10-10 2023-07-04 Marathon Petroleum Company Lp Methods and systems for enhancing processing of hydrocarbons in a fluid catalytic cracking unit using a renewable additive
US11802257B2 (en) 2022-01-31 2023-10-31 Marathon Petroleum Company Lp Systems and methods for reducing rendered fats pour point

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2007068798A2 (fr) * 2005-12-12 2007-06-21 Neste Oil Oyj Procede de fabrication d'hydrocarbures
US20080052983A1 (en) * 2006-08-16 2008-03-06 Energy & Environmental Research Center Foundation Optimal energy pathway to renewable domestic and other fuels
US20090162264A1 (en) * 2007-12-21 2009-06-25 Mccall Michael J Production of Aviation Fuel from Biorenewable Feedstocks
US20090253947A1 (en) * 2008-04-06 2009-10-08 Brandvold Timothy A Production of Blended Fuel from Renewable Feedstocks
US20130090502A1 (en) * 2011-10-07 2013-04-11 Neste Oil Oyj Process for manufacture of liquid fuel componenst from renewable sources

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6875339B2 (en) * 2003-03-07 2005-04-05 Conocophillips Company Octane improvement of a hydrocarbon stream
US20060264684A1 (en) * 2005-05-19 2006-11-23 Petri John A Production of diesel fuel from biorenewable feedstocks
DK2296810T3 (da) * 2008-06-25 2022-05-23 Shell Int Research Fremgangsmåde til fremstilling af paraffinholdige carbonhydrider fra råmaterialer omfattende glycerider og/eller fedtsyrer
US9200207B2 (en) * 2011-05-31 2015-12-01 University Of Central Florida Research Foundation, Inc. Methods of producing liquid hydrocarbon fuels from solid plastic wastes

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2007068798A2 (fr) * 2005-12-12 2007-06-21 Neste Oil Oyj Procede de fabrication d'hydrocarbures
US20080052983A1 (en) * 2006-08-16 2008-03-06 Energy & Environmental Research Center Foundation Optimal energy pathway to renewable domestic and other fuels
US20090162264A1 (en) * 2007-12-21 2009-06-25 Mccall Michael J Production of Aviation Fuel from Biorenewable Feedstocks
US20090253947A1 (en) * 2008-04-06 2009-10-08 Brandvold Timothy A Production of Blended Fuel from Renewable Feedstocks
US20130090502A1 (en) * 2011-10-07 2013-04-11 Neste Oil Oyj Process for manufacture of liquid fuel componenst from renewable sources

Also Published As

Publication number Publication date
US20150057477A1 (en) 2015-02-26

Similar Documents

Publication Publication Date Title
US20150057477A1 (en) Systems and methods for producing fuel from a renewable feedstock
US8853476B2 (en) Production of diesel fuel from biorenewable feedstocks with heat integration
CA2699897C (fr) Production de carburant diesel a partir de matieres premieres renouvelables avec consommation d'hydrogene reduite
TWI390030B (zh) 由生物可再生原料製造柴油燃料
US8198492B2 (en) Production of transportation fuel from renewable feedstocks
US7982075B2 (en) Production of diesel fuel from biorenewable feedstocks with lower hydrogen consumption
US7982078B2 (en) Production of diesel fuel from biorenewable feedstocks with selective separation of converted oxygen
CA2863031C (fr) Procede de production de biocarburant a partir de matiere premiere renouvelable
US20150094506A1 (en) Systems and methods for producing fuel from a renewable feedstock
US20130261360A1 (en) Methods and apparatuses for processing renewable feedstocks
US8764855B2 (en) Process for producing a biofuel while minimizing fossil fuel derived carbon dioxide emissions
US8440875B1 (en) Method and apparatus for high acid content feed for making diesel and aviation fuel
US20140296590A1 (en) Methods and apparatuses for processing renewable feedstocks

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 14837622

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 14837622

Country of ref document: EP

Kind code of ref document: A1