EP2782981A1 - Improved device for the extraction of sulphur compounds, comprising a first pre-treatment reactor operating in a non-continuous manner, followed by a second piston-type pre-treatment reactor - Google Patents
Improved device for the extraction of sulphur compounds, comprising a first pre-treatment reactor operating in a non-continuous manner, followed by a second piston-type pre-treatment reactorInfo
- Publication number
- EP2782981A1 EP2782981A1 EP12788615.8A EP12788615A EP2782981A1 EP 2782981 A1 EP2782981 A1 EP 2782981A1 EP 12788615 A EP12788615 A EP 12788615A EP 2782981 A1 EP2782981 A1 EP 2782981A1
- Authority
- EP
- European Patent Office
- Prior art keywords
- reactor
- sodium hydroxide
- soda
- extraction
- pretreatment
- 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.)
- Ceased
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
- 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
- C10G53/12—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one alkaline treatment step
-
- 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
- C10G19/00—Refining hydrocarbon oils in the absence of hydrogen, by alkaline treatment
- C10G19/02—Refining hydrocarbon oils in the absence of hydrogen, by alkaline treatment with aqueous alkaline solutions
-
- 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
- C10G19/00—Refining hydrocarbon oils in the absence of hydrogen, by alkaline treatment
- C10G19/08—Recovery of used refining agents
-
- 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
- C10G21/00—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents
- C10G21/06—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents characterised by the solvent used
- C10G21/08—Inorganic compounds only
-
- 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
- C10G21/00—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents
- C10G21/06—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents characterised by the solvent used
- C10G21/12—Organic compounds only
-
- 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
- C10G21/00—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents
- C10G21/28—Recovery of used solvent
-
- 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
- C10G21/00—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents
- C10G21/30—Controlling or regulating
-
- 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
- C10G53/04—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one extraction step
- C10G53/06—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one extraction step including only extraction steps, e.g. deasphalting by solvent treatment followed by extraction of aromatics
Definitions
- the invention relates to the field of the extraction of sulfur compounds such as mercaptans, COS and rH 2 S from a hydrocarbon fraction. This selective extraction is done by contacting the hydrocarbon feedstock in the liquid phase with a sodium hydroxide solution.
- the disulfide-rich soda solution is brought into contact with a hydrocarbon phase, which makes it possible to extract the disulphides and thus regenerate the soda which can be reused at the top of the liquid-liquid extraction column.
- the parameters associated with the oxidation are chosen so as to oxidize almost all the sodium thiolates present in the sodium hydroxide. The process thus allows partially or completely desoldering a hydrocarbon cut, and generates another organic effluent heavily loaded with sulfur species.
- a problem inherent in this type of process is the fact that certain chemical species such as COS or H 2 S irreversibly form salts in the presence of sodium hydroxide, salts that accumulate in the soda loop. Too much salt in the soda loop eventually limits its performance. For this reason, purges and regular additions are operated on the loop.
- Another widespread practice is to pretreat the hydrocarbon upstream of the extraction column, in an enclosure containing a solution of soda. This pretreatment has the effect of consuming a portion of the sulfur species, especially the species forming salts. The soda solution used in the pretreatment is not regenerated. This pretreatment step may be carried out in a separate enclosure, or in the same enclosure as the extraction column, if the latter is partitioned into 2 separate capacities, as described in US Pat. No. 6,749,741.
- the pretreatment is generally discontinuous, and consists in injecting the charge into a capacity filled with a soda solution which is periodically changed. Due to the discontinuous operation of the pretreatment, the sodium concentration decreases with time, as does its extraction performance. When the pretreatment performance is too low, the aqueous phase containing the sodium hydroxide is renewed, which can be carried out for example between 1 and 10 times per month depending on the methods and the size of the enclosure used for pretreatment.
- the initial concentration of sodium hydroxide is generally set at a content of between 2% and 10% by weight.
- the soda-countercurrent extraction of the hydrocarbon phase leaving the pretreatment can be carried out in different types of extraction columns. Many technologies are known, such as those reported in the Handbook of Solvent Extraction (Krieger Publishing Company, 1991). These columns are generally designed to generate at least 2 theoretical extraction stages. A technology of extraction column often encountered is that of the perforated plates with weirs, because the counter-current extraction with soda is often carried out with a soda flow much lower than the flow of hydrocarbon. The ratio between the flow rates of hydrocarbon and soda can vary between 5 and 40. The soda content in the loop is
- I generally set at a content of between 15 and 25% by weight.
- the discontinuous operation of the pretreatment has the advantage of maximizing its performance with respect to continuous operation in a perfectly stirred type reactor.
- the contents of COS and H 2 S are on average greatly reduced by the pretreatment step.
- the sulfur species leaving the pretreatment including the majority species of the mercaptan type, have fluctuating concentrations depending on the age of the sodium hydroxide solution used in the pretreatment chamber.
- the fluctuations in total sulfur can thus for example vary from single to double at the counter-current extraction column inlet. Concentration fluctuations pose several problems because the steps of mercaptan extraction, sodium thiolate oxidation and sodium hydroxide regeneration operate in steady state. Thus, several problems can appear:
- the quantity of mercaptans leaving the pretreatment can be as high as at the pre-treatment inlet, or even higher because of a salting out of mercaptans linked to the previous accumulation of a large amount of sodium thiolates and the low concentration of sodium hydroxide.
- waves of high concentrations of total sulfur may be present at the countercurrent extraction inlet, which can potentially generate liquid-liquid extraction efficiency losses in the column if the flow rate of soda in the n-loop is not enough to treat the highest concentrations.
- waves of mercaptans in the hydrocarbon then generate waves of sodium thiolates in the soda at the bottom of the extractor.
- the excessive concentration of sodium thiolates in the oxidizer can lead to a partial conversion to disulfide and thus a sodium thiolate referral in quantity in the regenerated sodium hydroxide at the top of the extraction column. This can also decrease the performance of the extraction column.
- the hydrocarbon entering the countercurrent extraction column contains little sulfur, so the concentration of sodium thiolate in the soda at the bottom of the extraction is low.
- the amount of air is then in excess.
- the dissolved oxygen in the sodium hydroxide is not consumed by the residual sodium thiolates, and is returned directly into the extractor with the regenerated sodium hydroxide.
- the oxygen present in the regenerated sodium hydroxide can then react with the mercaptans and produce disulfides within the extractor. These disulfides are then extracted by the hydrocarbon phase to be treated directly in the extraction column, so the overall performance of the process is reduced.
- FIG. 1 shows a version of the device according to the prior art.
- the pretreatment is carried out in a single enclosure (2).
- the extraction column (4) is fed with the feedstock resulting from the pretreatment (3) and with the regenerated soda (6).
- the regeneration loop of sodium hydroxide consists of an oxidizer (9) and a three-phase settling tank (12) for separating the air injected at (8) and withdrawn at (14) from an organic phase. injected
- the regenerated sodium hydroxide is reinjected into the extraction column via (6).
- FIG. 2 represents a version of the invention for which the pretreatment is carried out in two steps: a first discontinuous step (2) and a second step in a continuous piston-type co-current reactor (16).
- Fresh sodium hydroxide is introduced into the reactor (16) at point (15).
- the sodium hydroxide mixture and the hydrocarbon phase are separated in the settling tank (17), and the hydrocarbon phase is then injected at the bottom of the extraction column (4).
- the regeneration loop of the soda is identical to that of Figure 1.
- a portion of the pretreatment soda is extracted by the line (18).
- FIG. 3 represents an example of evolution of the sulfur content in mercaptan form (bold line), in sulfur in COS form (dashed) and in H 2 S form (fine line) in the hydrocarbon phase at the column outlet of extraction during the total period of use of the pretreatment soda in a process according to the prior art with a single batch pre-treatment reactor with sodium hydroxide.
- FIG. 4 represents an example of evolution of the sulfur content in mercaptan form (bold line), in sulfur in COS form (dotted line) and in H 2 S form (fine line) in the phase. hydrocarbon at the outlet of the extraction column during the total period of use of the sodium hydroxide in the discontinuous stage of the pretreatment system of the process according to the invention.
- the method according to the invention proposes to partially remedy the performance problems of the extraction process related to fluctuations in the contents of sulfur compounds in the stream obtained at the outlet of the pretreatment stage.
- the object of the invention is to provide a pretreatment which generates fewer fluctuations in sulfur compounds than in the pretreatment described according to the prior art, while improving its operation.
- the pretreatment of the hydrocarbon feedstock is carried out in two steps:
- the second pretreatment step is composed of a reactor supplied in cocurrent, ascending or descending, between the hydrocarbon phase to be refined and a sodium phase.
- the two phases are in contact in the reactor, which makes it possible to continue the extraction of the various acidic chemical species present in the hydrocarbon.
- the soda used here may be a new soda solution, between 5% and 21%, but may also be a spent soda solution recovered from the main loop of the extraction process, for example during purges carried out to renew the composition. > soda.
- the invention also has better performance than a continuous reactor of identical total size, even at identical levels of sodium consumption.
- the continuous step is carried out in a piston type reactor.
- the piston nature of the reactor means that the phases are transported in a preferred direction, that the compositions of the two phases evolve progressively from the inlet to the outlet of the reactor, and there is no axial mixing between the different species. reactive.
- Pe where U is the average rate of passage of the hydrocarbon in the reactor, L is the length of the reactor, D ax is the axial dispersion coefficient of the hydrocarbon in the reactor.
- the usual range of Peclet number is 1 ⁇ Pe ⁇ 50.
- the range of Peclet in the context of the present invention is 3 ⁇ Pe ⁇ 10, and more preferably 3 ⁇ Pe ⁇ 5.
- the linear velocity U is determined as the ratio of the hydrocarbon phase flow rate over the reactor section.
- the axial dispersion coefficient of the hydrocarbon phase Dax is determined by a tracing measurement, for example of the colorimetric type, which consists in introducing a colored wafer into the reactor inlet and monitoring its evolution at the reactor outlet.
- the output signal more or less spread, relates to the axial dispersion coefficient by methods well known to those skilled in the art.
- the piston reactor will be filled with a static mixer-type packing.
- static mixer-type packing Several industrial suppliers offer static mixer geometries. These include in particular and not exclusively static contactors models SMX ® type sold by Sulzer Chemtech or KMX ® model marketed by Kenics Company (PA Schweitzer, Handbook of separation techniques for chemincal engineers, 3rd Ed., Me Graw Hill, NY, 1997; Theron, F. Sauze, N.
- the sodium hydroxide used in the second continuous pre-treatment reactor (16) comes from the regeneration loop of the extractor soda.
- the sodium hydroxide used in the second continuous pre-treatment reactor (16) is taken between the outlet of the soda of the extractor (4) and the oxidizer (9).
- the present invention relates to a process for extracting sulfur compounds present in a hydrocarbon, in the case where the majority sulfur species are mercaptans, denoted RSH, for example methanethiol CH 3 SH, ethanethiol C 2 H 5 SH, propanethiol C3H7SH, and or other sulfur species are also present, such as H 2 S hydrogen sulfide or COS carbon oxysulfide.
- RSH mercaptans
- Figure 1 illustrates a process used to extract the sulfur species according to the prior art.
- the hydrocarbon fraction 1 enters a pretreatment chamber 2 pre-filled with a dilute sodium hydroxide solution at a concentration of between 2% and 10% by weight.
- the treated hydrocarbon feedstock exits the pretreatment via the pipe 3.
- the sodium hydroxide solution in the enclosure (2) is renewed according to an operating cycle of between 3 and 30 days, and depending on the age of the soda, the pretreatment extracts a variable amount of sulfur species, including mercaptans.
- the hydrocarbon then enters a countercurrent extraction column (4) from the bottom of the column.
- the extraction column (4) is also fed with a regenerated sodium hydroxide solution (6) at the top of the column.
- the concentration of sodium hydroxide is then between 15 and 25%.
- the function of column (4) is to extract the majority of the mercaptans still present in the hydrocarbon.
- the hydrocarbon thus refined exits the column (4) through line (5).
- the soda leaving the column (4) through the pipe (7) said spent soda is loaded with species of sodium thiolate RS-Na types, corresponding to mercaptans extracted, dissociated and recombined with Na + sodium ions.
- the flow (7) enters an oxidation reactor, also supplied with air by the pipe (8).
- the presence of air and a catalyst dissolved in the sodium hydroxide solution promote the oxidation reaction of sodium thiolates to disulphides noted RSSR.
- the catalyst used may be of the family of cobalt phthalocyanines.
- the multiphase medium leaving the reactor via line (11) is sent to a separation chamber (12).
- a flow (10) of gasoline cut or other hydrocarbon is injected into the soda solution upstream of the enclosure (12), for example in the pipe (11). It can also be injected into the pipe (7).
- the soda thus regenerated is returned to the top of the extraction column (4) via the pipe (6).
- a separating flask is added on the line (6) to optimize the extraction of disulfides with the hydrocarbon cut.
- the hydrocarbon cut (10) used to extract the disulfides is injected into the line (6), and then decanted into the additional separation flask.
- the hydrocarbon cut then leaving the additional balloon is sent to the line (7).
- FIG. 2 illustrates a version of the method according to the invention.
- a second pretreatment step has been added to the scheme of the process.
- This second stage is composed of a continuous reactor (16) fed with the hydrocarbon leaving the first discontinuous pretreatment stage (2).
- the reactor (16) is also fed with a sodium phase (15) injected into the pipe conveying the hydrocarbon between the two stages, or injected directly into the reactor.
- the injected sodium hydroxide is at a concentration of between 6% and 21% by weight in water.
- the sodium hydroxide introduced has a soda concentration of between 6% and 15% and even more preferably in a range of between 6% and
- the volume of the second piston reactor is between 0.1 and 3 times, and preferably between 0.5 and 1.5 times the volume of the first batch reactor.
- the flow rate of sodium hydroxide is low relative to the hydrocarbon flow rate, the volume flow rate ratio between the hydrocarbon feedstock and the sodium hydroxide is between 10 and 100,000, and preferably between 500 and 3000.
- the two sodium and hydrocarbon phases circulate cocurrently in the reactor.
- the piston nature in the reactor can be ensured in various ways, for example by dividing the reactor volume into separate compartments, separated by baffles.
- the two-phase mixture leaving the reactor (16) is sent to a decanter (17) to separate the sodium phase (18) from the hydrocarbon phase (3), which is conveyed to the countercurrent extraction column (4). ).
- the soda (18) can be reintroduced at a point of the second piston reactor located approximately mid-length of said reactor.
- a variant of the process consists in recycling part of the flow (18) of soda to the inlet
- the soda used in the second continuous pretreatment reactor (16) may be derived from the regeneration loop of the extractor soda, and preferably at a point (7) situated between the outlet of the soda of the extractor (4) and the oxidizer (9).
- the process is in all respects similar to that described in FIG. .
- the pretreatment is composed of a 12 m 3 prewash flask filled 2/3 of a 6% weight soda solution, renewed every 9 days.
- the hydrocarbon feedstock to be treated has a flow rate of 30 m 3 / h, and contains 146 ppm (weight S) of methyl mercaptans, 10 ppm (weight S) of COS and 7 ppm (weight S) of H 2 S.
- the composition of the hydrocarbon at the pre-treatment outlet as a function of time is obtained by simulation.
- the contents of RSH, COS and H 2 S are reported in Figure 3.
- the content of RSH varies sharply between the beginning and the end of life of the soda, in this case over a period of 9 days, which is detrimental to overall smooth operation of the process.
- the average sulfur content in the refined LPG leaving the process which is 2.05 ppm (weight S), is also obtained by simulation.
- This example constitutes the continuous version according to the prior art. This is to replace the pretreatment step discontinuously by a step continuously in a co-current reactor.
- the volume of the pretreatment reactor is identical to the flask used in Example 1, ie 12 m 3 .
- the amount of sodium hydroxide also unchanged is now introduced continuously into the reactor, with a constant injection and withdrawal rate.
- the injected 6% sodium hydroxide flow rate is 3.7 ⁇ 10 -2 m 3 / hr
- the advantage of this implementation in the pretreatment reactor is obviously to operate in a stationary manner, ie to stabilize the concentrations In this sense, this solution is relevant, making it possible to significantly reduce the average sulfur content in the refined LPG leaving the process.An average sulfur content in refined LPG of 1.27 ppm is obtained by simulation ( weight S).
- the same process now comprises an additional pretreatment step of the piston-flow co-current continuous reactor type, as described in FIG. 2, which is positioned downstream of the batch pretreatment reactor.
- the volume of the batch reactor is 6 m 3
- the volume of the continuous reactor is 6 m 3 , so that the total volume of the pretreatment is identical to Example 1.
- the batch pretreatment reactor is filled 2/3 of soda at 6% (weight), renewed every 4.5 days.
- the continuous piston reactor is fed with sodium hydroxide at 18% (weight) at a flow rate of 2 L / hr, so that the total amount of sodium hydroxide in the two pretreatment stages is identical to that of the single pre-treatment stage. of Example 1.
- composition of the hydrocarbon phase leaving the pretreatment obtained by simulation is reported in FIG. 4 as a function of time.
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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)
- Inorganic Chemistry (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
Description
Claims
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
FR1103593A FR2983205B1 (en) | 2011-11-24 | 2011-11-24 | IMPROVED PROCESS FOR THE EXTRACTION OF SULFUR COMPOUNDS USING A FIRST DISCONTINUOUSLY OPERATING PRETREATMENT REACTOR FOLLOWING A SECOND PISTON-TYPE PRETREATMENT REACTOR |
PCT/FR2012/000417 WO2013076383A1 (en) | 2011-11-24 | 2012-10-16 | Improved device for the extraction of sulphur compounds, comprising a first pre-treatment reactor operating in a non-continuous manner, followed by a second piston-type pre-treatment reactor |
Publications (1)
Publication Number | Publication Date |
---|---|
EP2782981A1 true EP2782981A1 (en) | 2014-10-01 |
Family
ID=47216351
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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EP12788615.8A Ceased EP2782981A1 (en) | 2011-11-24 | 2012-10-16 | Improved device for the extraction of sulphur compounds, comprising a first pre-treatment reactor operating in a non-continuous manner, followed by a second piston-type pre-treatment reactor |
Country Status (9)
Country | Link |
---|---|
US (1) | US9708550B2 (en) |
EP (1) | EP2782981A1 (en) |
JP (1) | JP5872709B2 (en) |
KR (1) | KR101958509B1 (en) |
CN (1) | CN103946344B (en) |
FR (1) | FR2983205B1 (en) |
IN (1) | IN2014CN04666A (en) |
RU (1) | RU2605087C2 (en) |
WO (1) | WO2013076383A1 (en) |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9523047B2 (en) * | 2014-06-12 | 2016-12-20 | Uop Llc | Apparatuses and methods for treating mercaptans |
Family Cites Families (12)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB728589A (en) * | 1951-10-04 | 1955-04-20 | British Petroleum Co | Improvements relating to the sweetening of mercaptan-containing hydrocarbon oils of petroleum origin |
FR1114509A (en) * | 1953-11-03 | 1956-04-13 | Electric Process Company | Improved process for oxidizing oxidizable substances using atomic oxygen |
US2945889A (en) * | 1955-12-21 | 1960-07-19 | Gloria Oil And Gas Company | Regeneration of spent caustic |
US3474027A (en) * | 1967-06-19 | 1969-10-21 | Phillips Petroleum Co | Plural stages of sulfur removal |
US4039389A (en) | 1975-11-03 | 1977-08-02 | Uop Inc. | Liquid-liquid extraction apparatus |
US4207174A (en) * | 1978-08-16 | 1980-06-10 | Uop Inc. | Liquid-liquid extraction apparatus and process |
SU1002289A1 (en) * | 1981-05-06 | 1983-03-07 | Всесоюзный научно-исследовательский институт углеводородного сырья | Process for isolating low-boiling mercaptanes from hydrocarbons |
US6749741B1 (en) * | 2001-12-20 | 2004-06-15 | Uop Llc | Apparatus and process for prewashing a hydrocarbon stream containing hydrogen sulfide |
CN1510109A (en) * | 2002-12-20 | 2004-07-07 | 中国石油天然气股份有限公司 | Combination process for deeply desulfurzing liquified petroleum gas and light olefin by solid alkali neutralizing agent and alkali |
AU2004320621B2 (en) * | 2004-06-02 | 2010-08-26 | Uop Llc | Apparatus and process for extracting sulfur compounds from a hydrocarbon stream |
US7772449B2 (en) * | 2007-08-01 | 2010-08-10 | Stone & Webster Process Technology, Inc. | Removal of acid gases and sulfur compounds from hydrocarbon gas streams in a caustic tower |
US9296956B2 (en) * | 2010-10-28 | 2016-03-29 | Chevron U.S.A. Inc. | Method for reducing mercaptans in hydrocarbons |
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2011
- 2011-11-24 FR FR1103593A patent/FR2983205B1/en active Active
-
2012
- 2012-10-16 WO PCT/FR2012/000417 patent/WO2013076383A1/en active Application Filing
- 2012-10-16 US US14/360,322 patent/US9708550B2/en active Active
- 2012-10-16 EP EP12788615.8A patent/EP2782981A1/en not_active Ceased
- 2012-10-16 RU RU2014125428/04A patent/RU2605087C2/en active
- 2012-10-16 IN IN4666CHN2014 patent/IN2014CN04666A/en unknown
- 2012-10-16 CN CN201280057707.5A patent/CN103946344B/en active Active
- 2012-10-16 JP JP2014542910A patent/JP5872709B2/en active Active
- 2012-10-16 KR KR1020147016895A patent/KR101958509B1/en active IP Right Grant
Non-Patent Citations (2)
Title |
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None * |
See also references of WO2013076383A1 * |
Also Published As
Publication number | Publication date |
---|---|
US9708550B2 (en) | 2017-07-18 |
CN103946344B (en) | 2016-03-23 |
RU2014125428A (en) | 2015-12-27 |
FR2983205A1 (en) | 2013-05-31 |
CN103946344A (en) | 2014-07-23 |
JP2015501861A (en) | 2015-01-19 |
KR101958509B1 (en) | 2019-03-14 |
JP5872709B2 (en) | 2016-03-01 |
IN2014CN04666A (en) | 2015-09-18 |
RU2605087C2 (en) | 2016-12-20 |
US20140319025A1 (en) | 2014-10-30 |
WO2013076383A1 (en) | 2013-05-30 |
KR20140096140A (en) | 2014-08-04 |
FR2983205B1 (en) | 2015-03-20 |
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