Classifications

• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10B—DESTRUCTIVE DISTILLATION OF CARBONACEOUS MATERIALS FOR PRODUCTION OF GAS, COKE, TAR, OR SIMILAR MATERIALS
  • C10B57/00—Other carbonising or coking processes; Features of destructive distillation processes in general
  • C10B57/04—Other carbonising or coking processes; Features of destructive distillation processes in general using charges of special composition
  • C10B57/06—Other carbonising or coking processes; Features of destructive distillation processes in general using charges of special composition containing additives
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10B—DESTRUCTIVE DISTILLATION OF CARBONACEOUS MATERIALS FOR PRODUCTION OF GAS, COKE, TAR, OR SIMILAR MATERIALS
  • C10B55/00—Coking mineral oils, bitumen, tar, and the like or mixtures thereof with solid carbonaceous material
  • C10B55/02—Coking mineral oils, bitumen, tar, and the like or mixtures thereof with solid carbonaceous material with solid materials
• • 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
  • C10G9/00—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
  • C10G9/005—Coking (in order to produce liquid products mainly)

Definitions

• This invention relates to a delayed coking process for treating heavy hydrocarbon oils containing undesired sulfur and nitrogen compounds.
• Delayed coking has been practiced for many years.
• the process utilizes thermal decomposition of heavy liquid hydrocarbons to produce coke, gas and liquid product streams of varying boiling ranges.
• the resulting coke is generally treated as a low value by-product, but is recovered for various uses, depending upon its quality.
• the feedstock is first introduced into a fractionating column where lighter materials are recovered from the top and the bottoms are then sent to a coking furnace where they are rapidly heated to a coking temperature in the range of 480° to 530°C and then fed to the coking drum.
• Coking units are typically configured with two parallel drums and operated in a swing mode. When one of the drums is Filled with coke, the feed is transferred to the empty parallel drum. Liquid and gas streams from the coke drum are fed to the coking product fractionator.
• Any hydrocarbon vapors remaining in the coke drum are removed by steam injection.
• the coke is cooled with water and then removed from the coke drum using hydraulic and/or mechanical means.
• the hot mixed fresh and recycle feedstream is introduced into a coke drum maintained at coking conditions of temperature and pressure where the feed decomposes or cracks to form coke and volatile components.
• the volatile components are recovered as vapor and transferred to the coking unit product fractionator.
• Heavy gas oil from the fractionator is added to the flash zone of the fractionator to condense the heaviest components from the coking unit product vapors.
• the heaviest fraction of the coke drum vapors can be condensed by other techniques, such as heat exchange, but- in commercial operations it is common to contact the incoming vapors with heavy gas oil in the coking unit product fractionator.
• Conventional heavy recycle oil is comprised of condensed coking unit product vapors and unflashed heavy gas oil.
• the catalyst is used to promote the cracking of the heavy hydrocarbon compounds and the formation of the more valuable liquids that can be subjected to hydrotreating processes downstream to form transportation fuels.
• the catalyst and any additive(s) remain in the coking unit drum with the coke if they are solids or are present on a solid carrier; if the catalyst(s) and additive(s) are soluble in the oil, they are carried with the vapors and remain in the liquid products. Processes have been disclosed for modifying the properties of the coke formed in the coking unit to obtain a particular coke product.
• a delayed coking process is described in USP 4,713, 168 in which Lewis acids, such as aluminum chloride, aluminum bromide, boron fluoride, zinc chloride and stannic chloride are used to obtain a premium coke having increased particle size.
• the additive and feedstock are introduced into the coking drum together.
• the additive can be in powder form or in liquid form if the feedstock is at a temperature above the melting point of the additive.
• the amount of the additive is a function of the feedstock used and the coking conditions employed. For example, 0.01 to about 5.0 percent by weight of additive based on the feedstock are used.
• additives based on polymeric materials with molecular weight in the range of from 1 ,000 to about 30,000 g/gmol is described in USP 7,658,838.
• the polymeric materials are selected from polyoxyethylene, polyoxypropylene, polyoxyethylene-polyoxypropylene copolymer, ethylene diamine tetra aikoxylated alcohol of polyoxyethylene alcohol, ethylene diamine tetra aikoxylated alcohol of polyxopropylene-polyoxyethylene alcohols and mixtures thereof and having a molecular weight from about 1,000 to about 30,000.
• the polymeric additive which is effective for the formation of substantially free-flowing shot coke is introduced into the feedstock at a point upstream of the second heating zone, between second heating zone and coking zone, or both.
• a delayed coking process is described in USP 7,303,664 that utilizes metal complexes, where the metal is selected from the group consisting of vanadium, nickel, iron, tin, molybdenum, cobalt and sodium.
• the additives enhance the production of free- flowing shot coke during delayed coking.
• the feedstock is subjected to treatment with one or more additives at effective temperatures, i.e., from 70°C-500°C.
• the additives can be in liquid or solid form.
• the additives include metal hydroxides, naphthenates and/or carboxylates, metal acetylacetonates, Lewis acids, metal sulfides, metal acetate, metal carbonates, high surface area metal-containing solids, inorganic oxides and salts of oxides, of which the basic salts are preferred additives.
• a process is described in USP 7,645,375 in which low molecular weight hydrocarbons are used as additives to produce free-flowing shot coke.
• the feedstock is subjected to treatment with one or more additives at effective temperatures 70°C-500C.
• the additives include one- and two-ring aromatic systems having from about one to four alkyl substituents, which alkyl substituents contain about one to eight carbon atoms, preferably from about one to four carbon atoms.
• the one or more rings can be aromatic rings only or aromatic rings containing nitrogen, oxygen, sulfur.
• the additives which include benzene, toluene, xylenes, methyl naphthalenes, dimethylnaphthates, indans, methyl indans, pyridine, methylpyridines, quinoline, and methylquinolines, are used in the concentration range of from 10 ppmw - 30,000 ppmw.
• a delayed coking process is described in USP 7,306,713 wherein metal free additives are used to produce free-flowing shot coke.
• the additives include elemental sulfur, high surface area substantially metal-free solids, such as rice hulls, sugars, cellulose, ground coals, ground auto tires; inorganic oxides such as fumed silica; salts of oxides, such as ammonium silicate and mineral acids such as sulfuric acid, phosphoric acid, and acid anhydrides.
• the additives include metal salts containing a metal selected from the group consisting of alkali metals, alkaline earth metals, and mixtures thereof.
• Gaseous hydrogen and hydrogen donor solvents are also utilized to enhance the coking unit product yields and quality. Hydrogen is used to stabilize the free radicals formed to increase liquid yields and, as a necessary result, to decrease the coke yield.
• a delayed coking process is described in U.S. patents 4,698, 147 and 4,178,229 in which a heavy hydrocarbon oil is admixed with a hydrogen donor diluent boiling in the range 200-540°C.
• the spent hydrogen donor is separated from the delayed coker products, regenerated and then recycled back to the coking unit.
• USP 4,797, 197 describes a delayed coking process wherein hydrogen gas is injected to stabilize a hydrocarbon compound incapable of further bimolecular reaction with another radical. This reaction is the reverse of coking reaction and hence minimizes coke production.
• references discussed above use additives/catalysts to improve the coke quality, but none of the references disclose a suitable, cost-effective additive, catalyst or adsorbent that can selectively remove the HPNA molecules from the liquid coking unit products to thereby enhance the quality of those products.
• a problem thus exists for producing transportation fuels from residual feedstocks that are low in HPNA molecules.
• the feedstock contains metal compounds that remain in the coking unit product stream and are preferably removed or reduced prior to further processing of the various fractionator streams.
• the present invention broadly comprehends a process for enhancing the quality of products recovered from a coking unit product stream fractionator by the addition of one or more adsorbents to the coking unit product stream to adsorb heavy polynuclear aromatics and other polar compounds that include undesirable sulfur and/or nitrogen constituents.
• the one or more solid adsorbent material(s) are mixed with an intermediate fraction that is withdrawn from the coking product fractionator to form a slurry and this adsorbent slurry is combined with the coking product stream prior to its introduction into the coking product fractionator.
• the solid adsorbent drops to the bottom of the fractionator where it is mixed with the fractionator bottoms.
• the fractionator bottoms containing the solid adsorbent are mixed with fresh hydrocarbon feedstock that is thereafter introduced into the coking furnace, heated to the predetermined coking temperature and introduced into a coking unit drum.
• the solid adsorbent with the adsorbed sulfur- and nitrogen-containing compounds is deposited in the drum and is eventually removed with the coke.
• the mixing of the solid adsorbent material(s) with a portion of the intermediate fraction from the coking product fractionator can be accomplished in a mixing zone that is in fluid communication with the coking product stream.
• the apparatus can include an inline mixer.
• the adsorbents can be slurried in an appropriate transfer fluid in a batch mixing vessel with a continuous mixer of the mechanical or circulation type.
• the slurry is then pumped into the coking process feedstream at a predetermined rate to achieve the desired concentration of adsorbents in the feed.
• the adsorbent material is mixed with the coking unit feedstream in a mixing zone that is downstream of the coking product fractionator prior to its introduction into the coking furnace.
• the adsorbent material can be mixed with a portion of another component of the coking feedstream, e.g., the bottoms from the coking production fractionator or the fresh hydrocarbon feedstock, or a side stream containing both, in order to form a thoroughly mixed slurry.
• This slurry can be stored in a vessel for metering at a predetermined rate for mixing with the coking unit feedstream.
• the mixing zone comprehends both the step of preparing the adsorbent slurry and its subsequent introduction into, and mixing with the other component(s) of the coking unit feedstream.
• HPNA heavy polynuclear aromatic
• Adsorbent materials useful in the practice of the process of this invention include molecular sieves, silica gel, activated carbon, activated alumina, silica-alumina gel, clays, spent catalysts from refining operations, and mixtures of two or more of these materials.
• Zinc oxide can be added to enhance sulfur removal.
• the amount of adsorbent required as a percentage or proportion of the coking product stream can readily be determined based upon the quantity of undesired sulfur- and nitrogen-containing compounds that are to be removed and the relative activity of the adsorbent material(s) that are to be used.
• the amount of adsorbent added to the feedstock to the coking unit is from 0.1 W% to 20 W%. Significant reductions in compounds containing sulfur and nitrogen can be attained with the addition of 5 W% of an adsorbent, or a combination of adsorbents that are selected to move specific heterocyclic compounds that have been determined to be present by prior analysis.
• One or more materials can be used that have an ability to adsorb sulfur-containing polynuclear compounds, and one or more different materials can be used to adsorb nitrogen-containing compounds.
• Various methods and apparatus can be employed to assure an intimate contact between the adsorbent(s) and the compounds to be removed from the coking product stream, as well as the contact time required to obtain the desired reduction in these undesired compounds.
• the acidic adsorbents such as natural clays and synthetic zeolites are preferred as being more specific, or selective, for nitrogen removal; zinc oxide is particularly effective for sulfur removal.
• the polynuclear compounds to be adsorbed may be desirable to reduce the temperature of the coking product stream to enhance the adsorption and retention of these compounds.
• a significant proportion of the HPNA molecules are adsorbed and retained on the adsorbent particles, thereby reducing the nitrogen-containing compounds to a desired lower level. From 20% to 90% of the nitrogen-containing compounds can be adsorbed, depending upon the composition and the remaining activity of the spent catalyst.
• the solid adsorbent will descend to the bottom of the unit.
• Fig. 1 is a schematic illustration of a process flow diagram suitable for practicing the process of the invention in which the adsorbent is mixed with the feed to the product fractionator;
• Fig. 2 is a schematic illustration of a process flow diagram similar to Fig. 1 of alternative embodiment of a process for practicing the process of the present invention
• Fig. 3 is a schematic illustration of a process diagram of an embodiment in which the adsorbent is mixed with the coking unit furnace feed downstream of the product fractionator;
• Fig. 4 is a chart showing a plot of the thermo-gravimetric analysis data for the test sample of the example.
• Fig. 5 is a plot of boiling point data for compounds corresponding to the test sample.
• a delayed coking unit 10 that includes at least one drum ( 12), the coking unit producing a delayed coking product stream ( 14) and a coke product ( 16) that is retained in the drum.
• the coking product stream ( 14) is introduced into a coking product fractionator (20) to produce at least a bottoms fraction (22), an intermediate fraction (24) and a light fraction (28).
• a hydrocarbon feedstock ( 18) containing undesirable sulfur and/or nitrogen compounds is initially introduced into the lower portion of the coking product fractionator (20a) for preheating.
• a portion (24b) of the intermediate fraction (24) and at least one adsorbent material (32) that selectively adsorbs sulfur- and/or nitrogen-containing compounds are introduced into a mixing zone (30) to form an adsorbent slurry stream (34).
• the slurry is mixed with the coking product stream ( 14) to form mixed fractionator feedstream (36) which is introduced into the lower portion of the fractionator (20) where it is mixed with the bottoms fraction (22) and the fresh hydrocarbon feed ( 18) and is discharged from the fractionator (20) to form a mixed coking unit feedstream (38).
• the mixed coking unit feedstream (38) that includes the adsorbent material is introduced into the coking unit furnace (40) for heating to a predetermined coking temperature and then is passed as the heated mixed feedstream (42) to the delayed coking drum ( 12) to produce the delayed coking product stream ( 14).
• the adsorbent material (44) having adsorbed sulfur and/or nitrogen compounds is deposited with the coke ( 16) on the interior surface of the delayed coking drum ( 12).
• the delayed coking product stream has a reduced content of the sulfur and/or nitrogen compounds corresponding to those deposited with the coke in drum 12.
• a pair of coking drums (1 12a) and ( 1 12b) are utilized in accordance with the conventional practice in order to permit continuous operation of the coking unit ( 1 10).
• the heated mixed coking unit feedstream ( 142) is passed to a freshly cleaned coking drum ( 1 12a) and the processing continued until drum ( 1 12a) is full of coke.
• the hot feedstream ( 142) containing the adsorbent is then diverted to the other drum ( 1 12b) and drum ( 1 12a) is taken out of service for removal of the accumulated coke. This process is repeated until drum ( 1 12b) has filled with coke.
• the adsorbent ( 132) is mixed with a portion of fractionator stream ( 124b) in, for example, a separate mixing vessel ( 130) to form a slurry stream ( 134).
• the slurry is formed with a portion ( 124b) drawn from the side stream ( 124) of the coking product fractionation ( 120). The use of this sidestream provides for ease of dispersion of the adsorbent to form the slurry and attaining the desired predetermined viscosity of the slurry.
• the mixing zone (230) receives solid adsorbent feed (232) for mixing to form a slurry (233) with all, but preferably a portion of one or a combination of product fractionator bottom stream (222a), fresh hydrocarbon feed (218a) and their mixture (229).
• the adsorbent slurry (233) can be introduced from the mixing zone (230) directly into the coking unit furnace feedstream (238) via three-way valve 237, or into a storage tank (250) via three-way valve 235 from which it is metered into the coking furnace feedstream (238).
• Other aspects of the operation and apparatus schematically illustrated in Fig. 3 correspond to those described above in connection with Figs. 1 and 2.
• thermo-gravimetric analysis was undertaken in order to determine the effectiveness of the adsorption process of the invention using attapulgus clay.
• a feed of demetallized oil from the solvent deasphalting of a vacuum residue was passed through a bed of the attapulgus clay, after which the bed was washed with a paraffinic straight run naphtha and the clay dried at 20°C using a nitrogen stream.
• the dried clay was then subjected to TGA in which a 13.5 mg sample of the clay was placed in the test container under an atmosphere of helium and uniformly heated at the rate of 30°C per minute to a temperature of 900 °C.
• the weight loss of the sample was measured at intervals of 1 °C from a starting temperature of 24°C to 900°C.
• the TGA data was converted and is shown in Fig. 4 as both a plot of the cumulative weight loss A (ascending line) and the differential weight loss B (multiple peaks) of the sample during the test, the lower portion of the range below about 150°C having been omitted.
• the plot of the TGA cumulative weight loss data shows how much material remains on the adsorbent as a function of temperature or, conversely, the amount of hydrocarbons released from the solid pores as a function of temperature.
• the second plot of the differential weight loss is measured against the weight percent scale on the left side of the plot and indicates the percent lost between points on the cumulative weight lost curve.
• the polar molecules are adsorbed on the surface at the lower contact temperature and are gradually desorbed as the temperature increases.
• the sample contains hydrocarbons boiling in the range 24°C to 900°C.
• the hydrocarbons released from the solid material at low temperatures are partially due to the solvent naphtha used in the experiments to wash the solid sample and to moisture adsorbed during the storage.
• the sample contains about 45 W% of heavy molecules boiling above 440 °C, which is the temperature of the stream exiting the delayed coke drum.
• the attapulgus clay contains about 60 W% of hydrocarbons at 275°C and about 45 W% at 440°C, the latter being the stream temperature exiting the coking unit in accordance with the present invention.
• Fig. 5 the boiling point distribution of demetallized oil (DMO) and other common refinery streams at 500°C and above are indicated.
• the line at 520°C represents the nominal cut point between vacuum gas oil and vacuum residue.
• Table 1 includes the structural formulas and related data for several types of polynuclear aromatic molecules. A comparison of Figs. 4 and 5 indicates that the types of molecules adsorbed on the adsorbent clay are heavy polynuclear aromatic (HPNA) compounds.
• HPNA heavy polynuclear aromatic
• a demetallized oil is introduced into a coking unit with and without an adsorbent material and subjected to delayed coking at a coking furnace outlet temperature of 496°C and atmospheric pressure.
• Five W% of attapulgus clay having a 108 m 2 /g surface area and 0.392 cm 3 /g pore volume is added to the coking unit product stream to form the mixture for the adsorbent coking example.
• Table 2 The process flow diagram of the delayed coking unit is similar to that of Fig. 1 , except that the adsorbent is mixed with the D O.
• the coking product stream yield and its characteristics are summarized in Table 3, where LCGO is "light coker gas oil” and HCGO is “heavy coker gas oil”.
• the adsorbent substantially lowers the heteroatom content, particularly the nitrogen-containing HP A, and that of the heteroatom content in the coking product steam.
• the coke yield increases at the expense of the liquid product yield as more HPNAs are removed from the feedstream.

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• 2012
  • 2012-06-26 CN CN201280046545.5A patent/CN103890142B/zh not_active Expired - Fee Related
  • 2012-06-26 KR KR1020147005451A patent/KR101703398B1/ko not_active Expired - Fee Related
  • 2012-06-26 JP JP2014522832A patent/JP5801485B2/ja not_active Expired - Fee Related
  • 2012-06-26 US US13/533,431 patent/US9023192B2/en active Active
  • 2012-06-26 EP EP12735379.5A patent/EP2737008B1/en not_active Not-in-force
  • 2012-06-26 WO PCT/US2012/044212 patent/WO2013019335A1/en not_active Ceased

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