EP0527000A2 - Verfahren zur Entfernung von Schwefel - Google Patents

Verfahren zur Entfernung von Schwefel Download PDF

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Publication number
EP0527000A2
EP0527000A2 EP92306587A EP92306587A EP0527000A2 EP 0527000 A2 EP0527000 A2 EP 0527000A2 EP 92306587 A EP92306587 A EP 92306587A EP 92306587 A EP92306587 A EP 92306587A EP 0527000 A2 EP0527000 A2 EP 0527000A2
Authority
EP
European Patent Office
Prior art keywords
sorbent
copper
stream
elemental sulphur
process according
Prior art date
Legal status (The legal status 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 status listed.)
Withdrawn
Application number
EP92306587A
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English (en)
French (fr)
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EP0527000A3 (en
Inventor
Peter John Herbert Carnell
Peter Wood
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Imperial Chemical Industries Ltd
Original Assignee
Imperial Chemical Industries Ltd
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 Imperial Chemical Industries Ltd filed Critical Imperial Chemical Industries Ltd
Publication of EP0527000A2 publication Critical patent/EP0527000A2/de
Publication of EP0527000A3 publication Critical patent/EP0527000A3/en
Withdrawn legal-status Critical Current

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    • 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
    • C10G25/00—Refining of hydrocarbon oils in the absence of hydrogen, with solid sorbents
    • C10G25/003—Specific sorbent material, not covered by C10G25/02 or C10G25/03
    • 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
    • C10G53/00—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes
    • C10G53/02—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only
    • C10G53/08—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one sorption step

Definitions

  • This invention relates to a process for the removal of elemental sulphur from organic compounds.
  • Elemental sulphur is soluble, and is often present as a contaminant, in organic liquids such as carbon tetrachloride and hydrocarbons such as benzene and petroleum. Also organic polysulphides are often present in such liquids and these readily decompose to give elemental sulphur dissolved in the liquid. Elemental sulphur can also result from the reaction of sulphur compounds such as hydrogen sulphide with oxidising agents. Furthermore elemental sulphur has an appreciable volatility and may be present in gaseous hydrocarbon streams.
  • an active form of metallic copper as produced through the reduction of a reducible copper compound, can be used to remove elemental sulphur from streams of gaseous or liquid organic compounds, particularly elemental sulphur dissolved in liquid hydrocarbon streams.
  • the present invention provides a process for decreasing the content of elemental sulphur of a stream of gaseous or liquid organic material contaminated with elemental sulphur comprising contacting the stream with a sorbent containing metallic copper as an active constituent.
  • the process of the present invention is preferably conducted under conditions of temperature and pressure such that the organic stream is in the liquid state.
  • the process is effected at a temperature below 300 C, particularly below 150°C, and at pressures up to to 100 bar abs.
  • Organic liquids suitable for treatment by the present invention include hydrocarbon streams such as petroleum, kerosene, liquefied petroleum gas (LPG), natural gas liquid (NGL), aromatic liquid hydrocarbons, and liquefied natural gas (LNG).
  • the initial concentration of the elemental sulphur is usually from 1 to 200 ppm, and typically from 1 to 50 ppm, by weight.
  • the sorbent has a copper content of at least 30% by weight (expressed as the percentage of the copper (II) oxide present in the loss free sorbent after ignition of the sorbent at 900 ° C), and more usually from 50% to 90% by weight.
  • the ability of the sorbent to sorb elemental sulphur is also effected by the accessibility of the copper metal by the elemental sulphur.
  • a high copper metal surface area sorbent is more efficient at sorbing sulphur than a sorbent of comparable copper content but lower copper metal surface area.
  • Particularly efficient sorbents are those having copper metal surface areas in excess of 20 M 2.
  • a high copper metal surface area sorbent may be formed by the reduction of a copper compound, e.g. the oxide, carbonate, or nitrate, with a suitable reducing agent.
  • Suitable reducing agents include hydrogen, a compound decomposable to hydrogen in the presence of the sorbent, carbon monoxide, and mixtures of carbon monoxide and hydrogen.
  • the conditions under which the reduction of the copper compound is conducted may be similar to those be employed in the preparation of a copper based methanol synthesis catalyst from the oxidic precursor to such a catalyst.
  • the temperature at which the sorbent is reduced is will depend to some extent on the nature of the reducing agent: typically the temperature will be in the range 90 to 250 C, and is usually in the range 150 to 200 ° C.
  • the sorbent may prepared in the form of particulates similar in size to those conventionally used for the removal of reactive sulphur compounds, such as described in US patents US-4871710, US-4996181 and US-4983367.
  • the sorbent may be disposed in a single bed or more usually in a plurality of serially and/or concurrently arranged beds.
  • the flow of organic liquid through each bed would be at a rate sufficient to give a liquid hourly space velocity (LHSV) from 1 to 20 hr- 1 , and more usually from 1 to 10 hr- 1 .
  • LHSV liquid hourly space velocity
  • the organic streams to be treated will contain other contaminants in addition to elemental sulphur.
  • These other contaminants may include hydrogen sulphide, carbonyl sulphide, organic sulphur compounds, arsenides, and heavy metals such as mercury.
  • the metallic copper sorbent may be used to remove these contaminants in addition to the elemental sulphur. It is preferred, however, to remove these contaminants from the organic stream by conventional means, e.g. a sorbent comprising zinc oxide and/or copper oxide, prior to contacting the metallic copper sorbent, thereby minimising the amount required of the metallic copper sorbent.
  • Figure 1 is a schematic diagram of an elemental sulphur removal process of the present invention.
  • Figure 1 shows an organic liquid feed stream (1) contacting one of two interchangeable contaminant removal reactors (2a, 2b).
  • Reactors (2a, 2b) are used to remove at least some of the reactive contaminants such as hydrogen sulphide, carbonyl sulphide as listed above and may contain a sorbent such as zinc and/or copper oxide.
  • the stream (3) is freed of the aforesaid reactive contaminants but may contain by-products such as water and carbon dioxide.
  • Stream (3) is then passed through one of two beds (4a, 4b) effective to sorb at least some of the byproducts produced in beds (2a, 2b) from the stream (3).
  • the byproduct-free stream then flows directly into the respective metallic copper sorbent bed (5a, 5b) wherein the dissolved elemental sulphur is removed to produce a desulphurised product stream (6).
  • the metallic copper sorbent is usually formed in situ by reduction of a precursor comprising a reducible copper compound. Reduction of the precursor may be accomplished by passing a hydrogen stream (8) which has been diluted with an inert stream (7) and heated in a heat exchanger (9) to a suitable reduction temperature through the bed of precursor and thereafter venting the effluent gas stream (10).
  • This may be achieved by re-reducing the spent metallic copper sorbent with a stream of hydrogen: typically the reduction may be effected using a hydrogen stream at 200-300 ° C.
  • the copper sulphide formed by reaction of the copper with the elemental sulphur is converted back to copper metal with the concurrent formation of hydrogen sulphide.
  • the hydrogen sulphide may be scrubbed from the hydrogen stream and then fed to a sulphur recovery plant, eg a Claus plant.
  • the first bed was 300 g of granules of an absorbent comprising a high surface area zinc oxide and a cement binder
  • the second bed was produced by reducing in situ 300g of granules formed from mixture of high surface area copper and zinc oxides and a cement binder.
  • the mixture contained 55% by weight of copper oxide.
  • the reduction was effected by means of a stream of hydrogen at a temperature of 180°C. It is estimated, from measurements performed on another sample of the mixture, that after reduction, the copper surface area of the second bed was 20 M 2.g- 1.
  • the spent copper/zinc oxide bed was then analysed and found to have a sulphur content of about 7.2% by weight. On examination by XRD it was found that cupric sulphide was present in the bed, but there was no cuprous sulphide, copper sulphate, or zinc sulphide. The absence of zinc sulphide in the spent copper/zinc oxide bed indicates that reactive sulphur compounds, such as hydrogen sulphide, present in the gasoline were absorbed by the first zinc oxide bed. The presence of cupric sulphide, rather than cuprous sulphide, in the spent copper/zinc oxide bed indicates that the copper could be regenerated by reduction with hydrogen since cupric sulphide is easier to reduce to metallic copper than cuprous sulphide.
  • the air in the reactor was displaced by nitrogen and the apparatus wrapped in aluminium foil to shield it from light (which effects decomposition of MMT). Hydrogen at 180°C was then passed through the series of beds to effect reduction of the copper compounds to metallic copper.
  • the reactor was then filled with a mixture of xylene (70% by weight) and heptane (30% by weight).
  • a solution containing 540 ppm by weight of MMT dissolved in the aforesaid xylene/heptane mixture was then passed through the series of beds at atmospheric pressure and at 22-25 ° C for 48 hours at a liquid hourly space velocity of 2 h- 1. Analysis of the solution before and after passage through the beds failed to reveal any change in the manganese content.
  • the reactor was then flushed with fresh solvent, purged with nitrogen.
  • the absorbents were then dried at 110°C and analysed for the presence of manganese. No manganese was detected in the zinc oxide sample while the reduced sulphided copper containing adsorbents contained about 300-500 ppm by weight of manganese. Since manganese is a possible contaminant of the cement employed as the granule binder, it is likely that this found manganese resulted from that contamination in view of the lack of detected change in the manganese content of the solution during passage through the beds. If all the MMT had been decomposed and absorbed by the absorbents, the average manganese content of the absorbent beds after the experiment would have been about 3% by weight.

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  • 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)
  • Treating Waste Gases (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Solid-Sorbent Or Filter-Aiding Compositions (AREA)
  • Treatment Of Liquids With Adsorbents In General (AREA)
EP19920306587 1991-08-06 1992-07-17 Sulphur removal process Withdrawn EP0527000A3 (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB919116907A GB9116907D0 (en) 1991-08-06 1991-08-06 Sulphur removal process
GB9116907 1991-08-06

Publications (2)

Publication Number Publication Date
EP0527000A2 true EP0527000A2 (de) 1993-02-10
EP0527000A3 EP0527000A3 (en) 1993-04-07

Family

ID=10699555

Family Applications (1)

Application Number Title Priority Date Filing Date
EP19920306587 Withdrawn EP0527000A3 (en) 1991-08-06 1992-07-17 Sulphur removal process

Country Status (8)

Country Link
EP (1) EP0527000A3 (de)
JP (1) JPH05192507A (de)
AU (1) AU2046392A (de)
CA (1) CA2075455A1 (de)
FI (1) FI923547A (de)
GB (1) GB9116907D0 (de)
NO (1) NO923083L (de)
ZA (1) ZA925529B (de)

Cited By (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1994028089A1 (en) * 1993-05-28 1994-12-08 Exxon Chemical Patents Inc. Sulfur and mercaptan removal from hydrocarbon streams containing reactive unsaturates
EP0816474A2 (de) * 1996-06-17 1998-01-07 Haldor Topsoe A/S Verfahren zur Reinigung eines Kohlenwasserstoffstroms
US5866749A (en) * 1993-05-28 1999-02-02 Exxon Chemical Patents Inc. Sulfur and thiol removal from reactive hydrocarbons
WO1999037740A1 (en) * 1998-01-23 1999-07-29 Exxon Research And Engineering Company Very low sulfur gas feeds for sulfur sensitive syngas and hydrocarbon synthesis processes
EP1262537A1 (de) * 2001-06-01 2002-12-04 Davy Process Technology Limited Verfahren und Anlage zur Hydroentschwefelung
US20110196181A1 (en) * 2005-12-23 2011-08-11 Basf Se Process for reacting an aromatic hydrocarbon in the presence of hydrogen
US8609048B1 (en) 2012-11-02 2013-12-17 Uop Llc Process for reducing corrosion, fouling, solvent degradation, or zeolite degradation in a process unit
CN110004595A (zh) * 2019-04-30 2019-07-12 太原理工大学 一种制备常低温ZnO/SMS复合煤气脱硫材料的方法
US11802257B2 (en) 2022-01-31 2023-10-31 Marathon Petroleum Company Lp Systems and methods for reducing rendered fats pour point
US11860069B2 (en) 2021-02-25 2024-01-02 Marathon Petroleum Company Lp Methods and assemblies for determining and using standardized spectral responses for calibration of spectroscopic analyzers
US11891581B2 (en) 2017-09-29 2024-02-06 Marathon Petroleum Company Lp Tower bottoms coke catching device
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
US11905479B2 (en) 2020-02-19 2024-02-20 Marathon Petroleum Company Lp Low sulfur fuel oil blends for stability enhancement and associated methods
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
US11970664B2 (en) 2021-10-10 2024-04-30 Marathon Petroleum Company Lp Methods and systems for enhancing processing of hydrocarbons in a fluid catalytic cracking unit using a renewable additive
US11975316B2 (en) 2019-05-09 2024-05-07 Marathon Petroleum Company Lp Methods and reforming systems for re-dispersing platinum on reforming catalyst
US12000720B2 (en) 2018-09-10 2024-06-04 Marathon Petroleum Company Lp Product inventory monitoring

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6274533B1 (en) * 1999-12-14 2001-08-14 Phillips Petroleum Company Desulfurization process and novel bimetallic sorbent systems for same
JP4609961B2 (ja) * 2000-01-28 2011-01-12 Ｊｘ日鉱日石エネルギー株式会社 硫黄化合物の除去方法

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB332910A (en) * 1929-02-26 1930-07-28 Stadtberger Huette Act Ges Improvements in or relating to the desulphurisation of liquid hydrocarbons
DE640204C (de) * 1931-12-04 1936-12-24 Hugo Kiemstedt Dr Verfahren zur Beseitigung der korrodierenden Eigenschaften und des ueblen Geruchs bei schwefelhaltigen Kohlenwasserstoffen
US2273298A (en) * 1938-09-23 1942-02-17 Albert Chester Travis Treatment of hydrocarbons
GB2108948A (en) * 1981-11-04 1983-05-25 Chevron Res Clay-based sulfur sorbent
US4996181A (en) * 1986-04-25 1991-02-26 Imperial Chemical Industries Plc Agglomerate absorbents comprising copper and zinc useful for sulphur compounds removal

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB332910A (en) * 1929-02-26 1930-07-28 Stadtberger Huette Act Ges Improvements in or relating to the desulphurisation of liquid hydrocarbons
DE640204C (de) * 1931-12-04 1936-12-24 Hugo Kiemstedt Dr Verfahren zur Beseitigung der korrodierenden Eigenschaften und des ueblen Geruchs bei schwefelhaltigen Kohlenwasserstoffen
US2273298A (en) * 1938-09-23 1942-02-17 Albert Chester Travis Treatment of hydrocarbons
GB2108948A (en) * 1981-11-04 1983-05-25 Chevron Res Clay-based sulfur sorbent
US4996181A (en) * 1986-04-25 1991-02-26 Imperial Chemical Industries Plc Agglomerate absorbents comprising copper and zinc useful for sulphur compounds removal

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
ANALYTICAL CHEMISTRY vol. 29, no. 7, July 1957, WASHINGTON pages 1039 - 1041 BLUMER 'REMOVAL OF ELEMENTAL SULFUR FROM HYDROCARBON FRACTIONS' *

Cited By (25)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1994028089A1 (en) * 1993-05-28 1994-12-08 Exxon Chemical Patents Inc. Sulfur and mercaptan removal from hydrocarbon streams containing reactive unsaturates
AU679759B2 (en) * 1993-05-28 1997-07-10 Exxon Chemical Patents Inc. Sulfur and mercaptan removal from hydrocarbon streams containing reactive unsaturates
US5866749A (en) * 1993-05-28 1999-02-02 Exxon Chemical Patents Inc. Sulfur and thiol removal from reactive hydrocarbons
EP0816474A2 (de) * 1996-06-17 1998-01-07 Haldor Topsoe A/S Verfahren zur Reinigung eines Kohlenwasserstoffstroms
EP0816474A3 (de) * 1996-06-17 1998-07-01 Haldor Topsoe A/S Verfahren zur Reinigung eines Kohlenwasserstoffstroms
WO1999037740A1 (en) * 1998-01-23 1999-07-29 Exxon Research And Engineering Company Very low sulfur gas feeds for sulfur sensitive syngas and hydrocarbon synthesis processes
US6103206A (en) * 1998-01-23 2000-08-15 Exxon Research And Engineering Co Very low sulfur gas feeds for sulfur sensitive syngas and hydrocarbon synthesis processes
EP1262537A1 (de) * 2001-06-01 2002-12-04 Davy Process Technology Limited Verfahren und Anlage zur Hydroentschwefelung
US20110196181A1 (en) * 2005-12-23 2011-08-11 Basf Se Process for reacting an aromatic hydrocarbon in the presence of hydrogen
US8609048B1 (en) 2012-11-02 2013-12-17 Uop Llc Process for reducing corrosion, fouling, solvent degradation, or zeolite degradation in a process unit
US11891581B2 (en) 2017-09-29 2024-02-06 Marathon Petroleum Company Lp Tower bottoms coke catching device
US12000720B2 (en) 2018-09-10 2024-06-04 Marathon Petroleum Company Lp Product inventory monitoring
CN110004595A (zh) * 2019-04-30 2019-07-12 太原理工大学 一种制备常低温ZnO/SMS复合煤气脱硫材料的方法
CN110004595B (zh) * 2019-04-30 2021-12-14 太原理工大学 一种制备常低温ZnO/SMS复合煤气脱硫材料的方法
US11975316B2 (en) 2019-05-09 2024-05-07 Marathon Petroleum Company Lp Methods and reforming systems for re-dispersing platinum on reforming catalyst
US11920096B2 (en) 2020-02-19 2024-03-05 Marathon Petroleum Company Lp Low sulfur fuel oil blends for paraffinic resid stability and associated methods
US11905479B2 (en) 2020-02-19 2024-02-20 Marathon Petroleum Company Lp Low sulfur fuel oil blends for stability enhancement and associated methods
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
US11906423B2 (en) 2021-02-25 2024-02-20 Marathon Petroleum Company Lp Methods, assemblies, and controllers for determining and using standardized spectral responses for calibration of spectroscopic analyzers
US11921035B2 (en) 2021-02-25 2024-03-05 Marathon Petroleum Company Lp Methods and assemblies for determining and using standardized spectral responses for calibration of spectroscopic analyzers
US11885739B2 (en) 2021-02-25 2024-01-30 Marathon Petroleum Company Lp Methods and assemblies for determining and using standardized spectral responses for calibration of spectroscopic analyzers
US11860069B2 (en) 2021-02-25 2024-01-02 Marathon Petroleum Company Lp Methods and assemblies for determining and using standardized spectral responses for calibration of spectroscopic analyzers
US11970664B2 (en) 2021-10-10 2024-04-30 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

Also Published As

Publication number Publication date
AU2046392A (en) 1993-02-11
CA2075455A1 (en) 1993-02-07
FI923547A0 (fi) 1992-08-06
EP0527000A3 (en) 1993-04-07
ZA925529B (en) 1993-04-28
GB9116907D0 (en) 1991-09-18
NO923083L (no) 1993-02-08
JPH05192507A (ja) 1993-08-03
NO923083D0 (no) 1992-08-05
FI923547A (fi) 1993-02-07

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