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
  • 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
  • C10G65/08—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only refining steps at least one step being a hydrogenation of the aromatic 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
  • 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
  • C10G65/043—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only refining steps at least one step being a change in the structural skeleton

Definitions

• the present invention is directed towards the improvement of distillate fuels. More particularly, the invention relates a process for reducing concentration of sulphur and polyaromatic compounds in those fuels.
• Sulphur can be removed by means of hydrotreating.
• the reactor temperature on fresh catalyst (start of run) is normally at the lower end of the above range, and as the catalyst deactivates the reactor temperature is raised to compensate for loss of catalyst activity.
• the end of the run is normally reached when the design temperature for the reactor is reached, which is decided by the metallurgy of the reactor.
• the run length is a very important consideration.
• a shorter run length means high costs due to a higher rate of catalyst replacement, and relatively more downtime (i.e. time off-stream) for catalyst change-out with a resultant loss of revenue due to reduced diesel fuel production.
• a hydrotreating unit is normally designed for a fixed LHSV (m 3 oil/m 3 catalyst/h) based on a required throughput of feedstock and a fixed reactor (catalyst) volume.
• Lower sulphur product can be obtained by lowering LHSV (e.g. by adding extra catalyst volume).
• LHSV m 3 oil/m 3 catalyst/h
• the start of run temperature can be raised to obtain a lower product sulphur at unchanged LHSV.
• the start of run temperature would typically need to be raised 35-45°C in order to reduce product sulphur from 500 wppm to 50 wppm.
• the addition reactor capacity represents a substantial investment
• the run length is reduced considerably.
• units designed to meet the more stringent sulphur specifications will make use of both possibilities.
• the catalyst volume could be increased by a factor 2-3 (LHSV reduced by a factor 2-3) and the start of run temperature increased by 10-20°C. By doing so the same run length could be achieved, because the rate of deactivation is lower at the lower LHSV and this compensates for the smaller temperature span between start of run and end of run.
• PAH Polyaromatic hydrocarbons
• IP 391-95 concentration of PAH can be measured by standard analysis method IP 391-95.
• PAH compounds react readily at hydrotreating conditions. Three-ring aromatic compounds are hydrogenated to two-ring aromatic compounds, which are hydrogenated to monoaromatic hydrocarbons. The monoaromatic compounds react slowly at typical distillate hydrotreating conditions to form naphthenes. The reactions are reversible and at high reaction temperatures and low hydrogen pressure the conversion of the PAH compounds is thermodynamically limited by equilibrium.
• a hydrotreating unit is designed to produce a diesel containing 50 wppm at a start of run temperature of 350°C.
• the reactor is designed to operate up to an average catalyst temperature of 400°C.
• the run length (based on a 50°C temperature span) is two years.
• the PAH content of the feed is 10 wt% and at start of run the product produced contains 2 wt% PAH.
• a new specification for diesel is imposed limiting the PAH content to 3 wt%. This is achievable at start of run but at the conditions employed in the unit, the 3% limit is exceeded at temperatures above 365°C. This means that the temperature span from start of run to end of run is reduced to 15°C, reducing run length to about one third. This is clearly unacceptable and would necessitate considerable investment in extra reactor volume or construction of a new unit at higher hydrogen pressure in order to maintain run length.
• the temperature at which the PAH equilibrium is met will depend on a number of factors including, hydrogen pressure, feed PAH content and composition, LHSV and product requirement. Thus, increasing pressure or reducing LHSV can extend the run length, but both measures require costly investments.
• Wakee et al. disclose a process, where sulphur compounds and aromatic compounds in destilled petroleum are hydrogenated in a process consisting of a conventional hydrogenator, where the sulphur in the sulpur compounds are converted to hydrogen sulphide, which is poiseneous to the down stream catalyst.
• the effluent is sent to a separator to remove the gas phase and hydrogen is added to the liquid separator effluent. Separation and hydrogen addition is repeated at least once before the liquid hydrocarbon/H 2 gas mixture is introduced into a second post treat reactor.
• the second reactor contains a noble metal catalyst being effective in reducing concentration of aromatic compound. This means that this process requires at least two separators and at least two hydrogen additions besides two reactors.
• the general object of the invention to avoid phase separation and hydrogen addition between hydrotreating reactor and post treat reactor in an improved process for the production of a low sulphur distillate fuel having a low content of polyaromatic hydrocarbons and thereby improved density and cetane number properties.
• the present invention is a process for achieving a low PAH content in distillate streams with only slight additional investment in reactor volume and without reduction in run length.
• the essence of the inventive process consists of cooling the effluent exiting the hydrotreating reactor and passing the cooled product through a small post treat reactor containing a suitable catalyst.
• the PAH content of the product exiting the hydrotreating reactor is reduced in the post treat reactor owing to the more favourable equilibrium conditions at the lower temperature.
• the end of run temperature in the main hydrotreating reactor is not limited by the PAH content of the product exiting the main reactor, and a lower overall reactor volume (main hydrotreater plus post treat reactor) is required for a given run length.
• the final bed of the main hydrotreating reactor is operated at lower temperature instead of using a post treat reactor.
• the process can be used to lower the density and raise the cetane number of the diesel product. Since the densities of PAH compounds are in general higher than the corresponding monoaromatic compounds, lowering the PAH content of the product also lowers the density of the product. In the same way, the cetane number and cetane index of PAH compounds are lower than the corresponding monoaromatic compounds, and reducing PAH content results in an increase in cetane number and cetane index.
• the petroleum distillates used in the present invention boil in the range 120-450°C and have a PAH content in the range 5-50 wt%.
• distillates include straight run fractions from an atmospheric crude distillation, light fractions from a vacuum crude distillation, the distillate obtained by fractionation of the product from a fluid catalytic cracking unit, distillate obtained by fractionation of oils from thermal cracking processes including cooking, and mixtures thereof.
• the process is particularly suitable for blends of distillate containing thermal cracked oils and fluid catalytic cracking distillate because these oil generally have a high PAH content.
• Feedstock is mixed with hydrogen, heated in the furnace (1) and passed through the hydrotreating reactor (2).
• the temperature employed in the post treat reactor will typically be in the range 250°C to 350°, and will typically be at least 50°C lower than the outlet temperature of the hydrotreater.
• the LHSV in the post treat- reactor will typically be in the range 2-20 m 3 oil/m 3 catalyst/h. and total pressure will be at the same level as that in the hydrotreating reactor.
• the catalyst used in the hydrotreating reactor may be any catalyst used for hydrotreating distillate streams and known in the art.
• the catalyst contains at least one metal on a porous refractory inorganic oxide support.
• metals having hydrotreating activity include metals from groups VI-B and VIII e.g. Co, Mo, Ni, W, Fe with mixtures of Co-Mo, Ni-Mo and Ni-W preferred.
• the metals are employed as oxides or sulphides.
• porous material suitable as support include alumina, silica-alumina, alumina-titania, natural and synthetic molecular sieves and mixtures hereof, with the alumina and silica-alumina being preferred.
• the catalyst used in the post treat reactor may be any catalyst used for hydrotreating distillate streams.
• Preferred catalysts are Ni-Mo, Co-Mo and Ni-W on alumina.
• the catalyst During operation, the catalyst must be in a sulphided condition and removal of H 2 S from the effluent by phase separation between the two reactors is not desired.
• the active metal on the catalyst is either presulphided prior to use by conventional means or in-situ sulphided by sulphur compounds in the effluent being introduced into the post treat reactor.
• the hydrotreating reactor section may consist of one or more reactors. Each reactor may have one or more catalyst beds.
• the function of the hydrotreating reactor is primarily to reduce product sulphur. Owing to the exothermic nature of the desulphurisation reaction, the outlet temperature is generally higher than the inlet temperature. Some reduction of PAH may be achieved in the hydrotreating reactor especially at start of run conditions. As the catalyst activity declines due to deactivation by carbonaceous deposits, sintering of the active phase and other mechanisms, the inlet temperature to the hydrotreating reactor is raised, resulting in an increased outlet temperature. This will result at some point in an increase in the PAH content in the effluent of the hydrotreater reactor due to equilibrium limitations. The temperature at which this occurs will depend on the amount and type of aromatic compounds in the oil, and the hydrogen partial pressure in the unit.
• the function of the post treat reactor is primarily to reduce the PAH content.
• the lower temperature in the post treat reactor ensures more favourable conditions for the thermodynamic equilibrium between PAH compounds and monoaromatic compounds.
• the reduction in PAH will result in a reduction in the product oil density and an increase in product oil cetane number, both of which are desirable. Only slight reduction in the sulphur content will be achieved at the conditions in post treat reactor.
• Feedstock A (Table 1) was hydrotreated in a semi-adiabatic pilot plant unit running with an outlet temperature of 390°C - a temperature, which normally is considered as end of run (EOR) conditions. The pressure was 30 Bar. Pure hydrogen was used as gas. Feedstock A is a mixture of 50% cycle oil and 50% straight run gas oil (SRGO).
• This product contains 20.6 wt% PAH, which would be typical for a product obtained at EOR conditions in a unit where the hydrogen partial inlet pressure is 30 bar (without taken into account the evaporated diesel), if the feedstock contains 50% cycle oil and 50% SRGO.
• Product A from example 1 is further hydrotreated at lower temperatures at different LHSV.
• the pressure is 30 Bar, which is identical to the pressure at which product A was obtained.
• the gas phase had a certain amount of H 2 S, which is a function of the amount of sulphur in the feed, the gas to oil ratio and the degree of desulphurisation.
• Product A was doped with a sulphur component in order to simulate the amount of H 2 S that would be in the gas phase without inter-stage removal of H 2 S (and other gases), when product A and the gas in equilibrium herewith is produced in the first hydrotreatment (Example 1).
• a Ni-Mo on alumina catalyst is used in this test. The results are shown in Table 3.
• Example 2 Temperature (°C) LHSV (h -1 ) SG 60/60 Di-aromatics (wt%) Tri-aromatics (wt%) PAH (wt%) 270 2.0 0.8698 7.8 4.0 11.8 270 6.0 0.8718 12.1 4.6 16.7 300 4.0 0.8679 6.3 3.4 9.7 300 10.0 0.8710 9.2 3.7 12.9 330 2.0 0.8665 6.4 2.6 9.0 330 6.0 0.8683 8.0 3.5 11.5
• Product A from Example 1 is further hydrotreated at a higher pressure than in Example 2.
• the specific gravity (SG 60/60) is 0.8638. It is clear that a higher hydrogen partial pressure increases the saturation of the poly-aromatic compounds.
• Product A was again doped with a sulphur component in order to simulate the amount of H 2 S that would be in the gas phase without inter-stage removal of H 2 S (and other gases), when product A and the gas in equilibrium herewith is produced in the first hydrotreatment (Example 1).
• a Ni-Mo on alumina catalyst is used in this test. There is virtually no further sulphur removal in this low-temperature hydrotreatment.
• the pressure was 32 Bar. Pure hydrogen was used as treat-gas. Hydrogen to oil ratio is 336 Nl/1.
• Feedstock B is a mixture of 50% light cycle oil (LCO) and 50% straight run gas oil (SRGO). A Co-Mo on alumina catalyst is used in this test. The properties of the products from the test are shown in Table 4.
• the two products have the same amount of poly-aromatic compounds, although they are quite different in their residual sulphur content.
• the reason for this result is that all aromatic compounds due to the high reaction temperature are close to the equilibrium between tri-aromatic ⁇ -> di-aromatic ⁇ -> mono-aromatic ⁇ -> naphthene, and therefore no effect of LHSV on the amount of PAH are observed.
• Product B from Example 4 is further hydrotreated at a lower temperature than in Example 4.
• T 300°C
• the specific gravity (SG 60/60) is 0.8496.
• a Ni-Mo on alumina catalyst is used in this test. Again it is clear that a large amount of the poly-aromatic compounds can be removed at lower temperature (and the same pressure) due to the shift in equilibrium. Again there is virtually no further sulphur removal in this low-temperature hydrotreatment.

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• Chemical & Material Sciences (AREA)
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• Chemical Kinetics & Catalysis (AREA)
• General Chemical & Material Sciences (AREA)
• Organic Chemistry (AREA)
• Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
• Catalysts (AREA)
• Liquid Carbonaceous Fuels (AREA)

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• 2001
  • 2001-01-12 EP EP01100722A patent/EP1120453A3/de not_active Withdrawn
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  • 2001-01-23 CN CN01104587A patent/CN1309163A/zh active Pending
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