CN102549114A - Processes for removing hydrogen sulfide from refined hydrocarbo streams - Google Patents
Processes for removing hydrogen sulfide from refined hydrocarbo streams Download PDFInfo
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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
- C10G75/00—Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general
- C10G75/04—Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general by addition of antifouling agents
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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
- C10G75/00—Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general
- C10G75/02—Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general by addition of corrosion inhibitors
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- 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
- C10G29/00—Refining of hydrocarbon oils, in the absence of hydrogen, with other chemicals
- C10G29/20—Organic compounds not containing metal atoms
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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
- C10G29/00—Refining of hydrocarbon oils, in the absence of hydrogen, with other chemicals
- C10G29/20—Organic compounds not containing metal atoms
- C10G29/22—Organic compounds not containing metal atoms containing oxygen as the only hetero atom
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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
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/10—Feedstock materials
- C10G2300/1037—Hydrocarbon fractions
- C10G2300/104—Light gasoline having a boiling range of about 20 - 100 °C
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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
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/10—Feedstock materials
- C10G2300/1037—Hydrocarbon fractions
- C10G2300/1044—Heavy gasoline or naphtha having a boiling range of about 100 - 180 °C
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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
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/10—Feedstock materials
- C10G2300/1037—Hydrocarbon fractions
- C10G2300/1048—Middle distillates
- C10G2300/1051—Kerosene having a boiling range of about 180 - 230 °C
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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
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/10—Feedstock materials
- C10G2300/1037—Hydrocarbon fractions
- C10G2300/1048—Middle distillates
- C10G2300/1055—Diesel having a boiling range of about 230 - 330 °C
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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
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/10—Feedstock materials
- C10G2300/1037—Hydrocarbon fractions
- C10G2300/1048—Middle distillates
- C10G2300/1059—Gasoil having a boiling range of about 330 - 427 °C
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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
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/10—Feedstock materials
- C10G2300/1077—Vacuum residues
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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
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/20—Characteristics of the feedstock or the products
- C10G2300/201—Impurities
- C10G2300/207—Acid gases, e.g. H2S, COS, SO2, HCN
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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
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/40—Characteristics of the process deviating from typical ways of processing
- C10G2300/4075—Limiting deterioration of equipment
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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
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/80—Additives
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- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
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- Preventing Corrosion Or Incrustation Of Metals (AREA)
Abstract
A method for reducing the amount of hydrogen sulfide present in refined hydrocarbon streams and reducing the amount of corrosion in processing equipment contacting the refined hydrocarbon stream The method includes adding a corrosion inhibitor to the ielined In drocarbon stream in contact with the processing equipment to protect the processing equipment and adding glyo\al to the refined hydr caib n stream in contact with the protected processing equipment The corrosion inhibitor includes an organic soluble compound having a nitrogen-containing ring.
Description
Invention field
The present invention relates generally to process the hydrocarbon medium, more particularly, the present invention relates to remove from the purified hydrocarbon stream method of hydrogen sulfide.
Background of invention
The hydrocarbon medium can contain hydrogen sulfide such as the purified hydrocarbon stream, and hydrogen sulfide is high corrosion and deleterious under very little concentration.Store, transportation (shipping, with truck carrying or pipeline) with process during, be health and safety concern item from the risk that is exposed to hydrogen sulfide of processing hydrocarbons medium.
Hydrogen sulfide scavenger can be used for removing hydrogen sulfide from the hydrocarbon medium.One type hydrogen sulfide scavenger is an oxalic dialdehyde.Oxalic dialdehyde production period, form acidic by-products usually.These by products can cause the erosion rate during hydrocarbon processing to improve.When oxalic dialdehyde was joined the purified hydrocarbon stream, the acidic by-products that is insoluble to the purified hydrocarbon stream can sedimentation from the purified hydrocarbon stream, becomes independent water.For example, this water can flow as the sprout in the pipeline along the bottom of processing or refinery's equipment or stagnate in the bottom of storage tank.This acidity water has high corrosion property and can in processing or refinery's equipment, cause fluting.
Need remove hydrogen sulfide and can not cause the improved method of processing units corrosive from the purified hydrocarbon stream.
Summary of the invention
In one embodiment; The method of the corrosive amount in the amount that is used for reducing the hydrogen sulfide that is present in the purified hydrocarbon stream being provided and being reduced in the processing units that contacts the purified hydrocarbon stream; Said method comprise in the purified hydrocarbon stream that contacts with processing units add corrosion inhibitor with the protection processing units with to purified hydrocarbon stream that shielded processing units contacts in add oxalic dialdehyde, wherein said corrosion inhibitor comprises and has the organic soluble compound that contains azo-cycle.
Multiple embodiments provides the improved hydrogen removing method that is used for the purified hydrocarbon stream, and this method reduces hydrogen sulfide, and the corrosion of processing units is minimized.
Detailed Description Of The Invention
Only if context offers some clarification on other situation, otherwise singulative " ", " one " and " being somebody's turn to do " comprise the referent of plural number.The end points of describing all scopes of identical characteristic is capable of being combined independently, and comprises described end points.All reference are attached among this paper by reference.
Modifier " pact " comprises said numerical value when being used in combination with quantity, and has the implication (for example, comprise with specifically the relevant tolerance zone of measurement of quantity) of context regulation.
" optional " or " choose " is meant that incident or the situation described subsequently possibly take place perhaps possibly not take place; Perhaps specified subsequently material possibly exist or possibly not exist; And this description comprises the situation that incident or situation take place or material exists, and incident or situation does not take place or the non-existent situation of material.
In one embodiment; The amount that a kind of method is used for reducing the hydrogen sulfide that is present in the purified hydrocarbon stream be reduced in the processing units that contacts the purified hydrocarbon stream in the corrosive amount; Said method comprises: in the purified hydrocarbon stream that contacts with processing units, add corrosion inhibitor with the protection processing units; With to purified hydrocarbon stream that shielded processing units contacts in add oxalic dialdehyde, wherein said corrosion inhibitor comprises and has the organic soluble compound that contains azo-cycle.
The purified hydrocarbon stream can be the purified hydrocarbon stream of any kind that contains hydrogen sulfide.In one embodiment, the purified hydrocarbon stream includes, but not limited to gas oil, petroleum naphtha, FCC (fluid catalytic cracking) slurry oil, diesel-fuel, oil fuel, jet fuel, gasoline, kerosene or vacuum residuum.In one embodiment, the purified hydrocarbon stream can be at elevated temperatures.In another embodiment, the purified hydrocarbon stream can be under about envrionment temperature to about 150 ℃ temperature.In another embodiment, the purified hydrocarbon stream can be under about 40 ℃-Yue 100 ℃ temperature.
The processing units that contacts with the purified hydrocarbon stream can be the equipment of any kind that can be used for processing this purified hydrocarbon stream, such as pipeline and storage tank.Stand the corrosive processing units and be generally the processing units of processing by carbon steel, but the processing units of any kind can be protected.
Corrosion inhibitor comprises and has the organic soluble compound that contains azo-cycle.In one embodiment, corrosion inhibitor is miscible in the purified hydrocarbon stream.
In one embodiment, contain azo-cycle and can be five-ring or six-ring.In one embodiment, contain azo-cycle and can be imidazolidine derivatives.In another embodiment, corrosion inhibitor can be the fatty acid imidazoline quinoline.In one embodiment, the fatty acid imidazoline quinoline has following structure:
Wherein R and R ' are C independently of one another
6-C
36Alkyl, thiazolinyl or aromatic group.In another embodiment, R and R ' are C independently of one another
8-C
22Alkyl, thiazolinyl or aromatic group.In another embodiment, R and R ' are C independently of one another
16-C
18Alkyl, thiazolinyl or aromatic group.In another embodiment, R and R ' are independently of one another for having the C of branched-alkyl
6-C
36Alkyl, thiazolinyl or aromatic group.In one embodiment, R can be stearyl, naphthyl, palmityl, oil base, inferior oil base or flax base.In one embodiment, R ' can be stearyl, naphthyl, palmityl, oil base, inferior oil base or flax base.
In one embodiment, fatty acid imidazoline quinoline compound includes, but not limited to Triple Pressed Stearic Acid tetrahydroglyoxaline, naphthenic acid imidazoline, palmitinic acid tetrahydroglyoxaline, oleic imidazolinone, linolic acid tetrahydroglyoxaline or linolenic acid tetrahydroglyoxaline.
In one embodiment, the fatty acid imidazoline quinoline can contain the mixture of two kinds or more kinds of fatty acid imidazoline quinoline compounds.
In one embodiment, the fatty acid imidazoline quinoline can prepare through the condensation reaction of at least a lipid acid and NSC 446.In one embodiment, lipid acid can have C
6-C
36Chain length.In another embodiment, lipid acid can have C
8-C
22Chain length.In another embodiment, lipid acid can have C
16-C
18Chain length.In one embodiment, lipid acid can comprise the natural acid derived from Yatall MA, oleic acid, Triple Pressed Stearic Acid, palmitinic acid, linolic acid, linolenic acid or naphthenic acid, perhaps can comprise the lipid acid of synthetic preparation.The lipid acid of synthetic preparation can comprise the acid with even number of carbon atoms or odd number carbon atom.In one embodiment, condensation reaction can be to the temperature of reaction up to about 400 ℉.In another embodiment, temperature of reaction can be about 200 ℉-Yue 400 ℉.
In another embodiment, contain azo-cycle and can be pyrimidine derivatives.In another embodiment, corrosion inhibitor can be the lipid acid pyrimidine.In another embodiment, the lipid acid pyrimidine has following structure:
R wherein
aAnd R
bBe C independently of one another
6-C
36Alkyl, thiazolinyl or aromatic group.In another embodiment, R
aAnd R
bBe C independently of one another
8-C
22Alkyl, thiazolinyl or aromatic group.In another embodiment, R
aAnd R
bBe C independently of one another
16-C
18Alkyl, thiazolinyl or aromatic group.In one embodiment, R
aAnd R
bIndependently of one another for having the C of branched-alkyl
6-C
36Alkyl, thiazolinyl or aromatic group.In one embodiment, R
aCan be stearyl, naphthyl, palmityl, oil base, inferior oil base or flax base.In one embodiment, R
bCan be stearyl, naphthyl, palmityl, oil base, inferior oil base or flax base.
In one embodiment, the lipid acid pyrimidine compound includes, but not limited to Triple Pressed Stearic Acid pyrimidine, naphthenic acid pyrimidine, palmitinic acid pyrimidine, oleic acid pyrimidine, linolic acid pyrimidine or linolenic acid pyrimidine.
In one embodiment, the lipid acid pyrimidine can contain the mixture of two kinds or more kinds of lipid acid pyrimidine compounds.
In one embodiment, the lipid acid pyrimidine can pass through at least a lipid acid and lipid acid-deutero-1, and the condensation reaction of 3-tn and Paraformaldehyde 96 prepares.In one embodiment, lipid acid can have C
6-C
36Chain length.In another embodiment, lipid acid can have C
8-C
22Chain length.In another embodiment, lipid acid can have C
16-C
18Chain length.In one embodiment, lipid acid can comprise the lipid acid that maybe can comprise synthetic preparation derived from the natural acid of Yatall MA, oleic acid, Triple Pressed Stearic Acid, palmitinic acid, linolic acid, linolenic acid or naphthenic acid.The lipid acid of synthetic preparation can comprise the acid with even number of carbon atoms or odd number carbon atom.In one embodiment, condensation reaction can be to the temperature of reaction up to about 400 ℉.In another embodiment, temperature of reaction can be about 200 ℉-Yue 400 ℉.
Can corrosion inhibitor be joined the purified hydrocarbon stream that contacts with processing units, with the protection processing units.In one embodiment, corrosion inhibitor is joined the purified hydrocarbon stream, this stream contacts processing units subsequently.In another embodiment, corrosion inhibitor is joined the purified hydrocarbon stream, should contact with processing units by stream simultaneously.
Adopt the mode of any routine that corrosion inhibitor is joined the purified hydrocarbon stream.In one embodiment, can corrosion inhibitor be injected in the purified hydrocarbon stream.In one embodiment, can corrosion inhibitor be injected in the purified hydrocarbon stream, and can be suitable for making corrosion inhibitor and any online some injection of purified hydrocarbon stream blended through the online injecting systems of routine.Can adopt the successive mode that corrosion inhibitor is joined the purified hydrocarbon stream, perhaps can one or more batch-mode add, and can repeat to add.
In another embodiment, when the purified hydrocarbon stream flows through pipeline, corrosion inhibitor is injected in the purified hydrocarbon stream.In one embodiment, when the purified hydrocarbon stream gets into pipeline, corrosion inhibitor is injected in the purified hydrocarbon stream.In another embodiment, corrosion inhibitor is injected in the purified hydrocarbon stream in storage tank.In another embodiment, when the purified hydrocarbon stream gets into storage tank, corrosion inhibitor is injected in the purified hydrocarbon stream.
Corrosion inhibitor disperses to get in the purified hydrocarbon stream, and finally contacts processing units and on processing units, deposit formation protective coating or film.Corrosion inhibitor can be suitable on processing units, forming any amount adding of protective coating or film.In one embodiment, based on the volume of purified hydrocarbon stream, the amount that corrosion inhibitor can about 2ppm volume-Yue 200ppm volume joins the purified hydrocarbon stream.In another embodiment, based on the volume of purified hydrocarbon stream, the amount that corrosion inhibitor can about 5ppm volume-Yue 100ppm volume joins the purified hydrocarbon stream.In another embodiment, based on the volume of purified hydrocarbon stream, corrosion inhibitor is joined the purified hydrocarbon stream with the amount of about 10ppm volume-Yue 100ppm volume.In another embodiment, based on the volume of purified hydrocarbon stream, corrosion inhibitor is joined the purified hydrocarbon stream with the amount of about 20ppm volume-Yue 100ppm volume.Corrosion inhibitor can add in single batch, perhaps can join the purified hydrocarbon stream by successive doses.
When the corrosion inhibitor contact arrangement, beginning uniform deposition on processing units.When the purified hydrocarbon stream that contains corrosion inhibitor continues the contact processing units, can on processing units, form protective coating.The time quantum that is suitable for forming protective coating depends on many factors, such as the temperature of the amount of corrosion inhibitor in the purified hydrocarbon stream, purified hydrocarbon stream, time quantum that the purified hydrocarbon stream contacts with processing units and when the purified hydrocarbon stream contact processing units its speed that moves.In one embodiment, after adding corrosion inhibitor in the purified hydrocarbon stream that contacts with processing units was at least about 5 minutes, corrosion inhibitor provided protective coating or film on processing units.In another embodiment, distance added corrosion inhibitor about 5 minutes-Yue 100 hours in the purified hydrocarbon stream that contacts with processing units, and corrosion inhibitor provides protective coating on processing units.In another embodiment, distance added corrosion inhibitor about 15 minutes-Yue 75 hours in the purified hydrocarbon stream that contacts with processing units, on processing units, formed protectiveness film or coating.In another embodiment, distance added corrosion inhibitor about 30 minutes-Yue 60 hours in the purified hydrocarbon stream that contacts with processing units, on processing units, formed protectiveness film or coating.In another embodiment, distance to heavy oil that processing units contact in added corrosion inhibitor about 1 hour-Yue 50 hours, formation protectiveness film or coating on processing units.In another embodiment, distance added corrosion inhibitor about 10 hours-Yue 40 hours in the purified hydrocarbon stream that contacts with processing units, on processing units, formed protectiveness film or coating.In another embodiment, distance added corrosion inhibitor about 12 hours-Yue 36 hours in the purified hydrocarbon stream that contacts with processing units, and corrosion inhibitor provides protective coating to processing units.
Oxalic dialdehyde is joined the purified hydrocarbon stream that contacts with shielded processing units, to reduce hydrogen sulfide.Oxalic dialdehyde is water-soluble aldehyde, and can comprise oxalic dialdehyde oligopolymer.Oxalic dialdehyde gets as 40% weightaqueous solution is commercially available.
Can adopt the mode of any routine that oxalic dialdehyde is joined the purified hydrocarbon stream.In one embodiment, can oxalic dialdehyde be injected in the purified hydrocarbon stream, and can be suitable for making oxalic dialdehyde with any online some injection of purified hydrocarbon stream blended through the online injecting systems of routine.Can adopt the successive mode that oxalic dialdehyde is joined the purified hydrocarbon stream, perhaps can one or more batch-mode add, and can repeat to add.
With any amount that is enough to the level of hydrogen sulfide in the purified hydrocarbon stream that is reduced in oxalic dialdehyde is joined the purified hydrocarbon stream.In one embodiment, based on the volume of purified hydrocarbon stream, the amount that oxalic dialdehyde can the about 3000ppm volume of about 1ppm-adds.In another embodiment, based on the volume of purified hydrocarbon stream, the amount that oxalic dialdehyde can about 10ppm volume-Yue 2000ppm volume adds.In another embodiment, based on the volume of purified hydrocarbon stream, the amount that oxalic dialdehyde can about 50ppm volume-Yue 1500ppm volume adds.In another embodiment, based on the volume of purified hydrocarbon stream, the amount that oxalic dialdehyde can about 100ppm volume-Yue 1200ppm volume adds.
Can be reduced in the hydrogen sulfide of any amount in the purified hydrocarbon stream, and the actual amount of remaining hydrogen sulfide depends on initial amount and changes.In one embodiment, hydrogen sulfide levels is reduced to 150ppm volume or still less, in gas phase, measures, based on the volume of purified hydrocarbon stream.In another embodiment, hydrogen sulfide levels is reduced to 100ppm volume or still less, in gas phase, measures, based on the volume of purified hydrocarbon stream.In another embodiment, hydrogen sulfide levels is reduced to 50ppm volume or still less, in gas phase, measures, based on the volume of purified hydrocarbon stream.In another embodiment, hydrogen sulfide levels is reduced to 20ppm volume or still less, in gas phase, measures, based on the volume of purified hydrocarbon stream.
Oxalic dialdehyde production period, form acidic by-products, and oxalic dialdehyde pH can be in about 3 scopes of about 2-.These by products can have high corrosion property.Oxalic dialdehyde is for based on water, and in whole purified hydrocarbon stream, after the initial dispersion, finally goes out with water sedimentation from heavy oil.This water has acid and corrodible processing units.Coating that on processing units, forms by corrosion inhibitor or film protection processing units, and reduce or eliminate the corrosion from acid water.
When oxalic dialdehyde being joined the purified hydrocarbon stream that contacts with shielded processing units, can continue to add corrosion inhibitor.Corrosion inhibitor will continue on processing units, to deposit, and maintain the protection on the processing units.This other corrosion inhibitor can about 1ppm volume-Yue 20ppm volume amount add, based on the volume of purified hydrocarbon stream.In another embodiment, the amount that this corrosion inhibitor can about 5ppm volume-Yue 10ppm volume adds, based on the volume of purified hydrocarbon stream.
In one embodiment, can add catalyzer, to strengthen the removal of hydrogen sulfide.In one embodiment, catalyzer is a quaternary ammonium salt.Catalyzer can be any suitable quaternary ammonium salt.In one embodiment, catalyzer has formula I:
R
1R
2R
3R
4N
+X- I
R wherein
1, R
2, R
3And R
4Independently of one another for alkyl with 1-30 carbon atom, have the aryl of 6-30 carbon atom or have the arylalkyl of 7-30 carbon atom; With X be halide-ions, sulfate radical, nitrate radical or carboxylate radical.Alkyl and aryl can be substituted or not be substituted.
In one embodiment, R
1For having the alkyl of 1-24 carbon atom.In one embodiment, R
2For alkyl with 1-24 carbon atom, have the aryl of 6-24 carbon atom or have the arylalkyl of 7-24 carbon atom.
In one embodiment, R
3And R
4Independent of separately having the alkyl of 1-24 carbon atom.In another embodiment, R
3And R
4Independent of separately having the alkyl of 1-4 carbon atom.
Alkyl includes, but not limited to methyl, ethyl, propyl group, sec.-propyl, butyl, isobutyl-, amyl group, hexyl, decyl or dodecyl.Aryl can be phenyl.Arylalkyl comprises and can be benzyl.Halide-ions can be cl ions, bromide anion or iodide ion.Sulfate radical can be methylsulfate.Nitrate radical can be the bisulfate ion nitrate radical.Carboxylate radical can be acetate moiety.
In one embodiment, quaternary ammonium salt is alkyl benzyl ammonium chloride or benzyl cocounut oil alkyl (C
12-C
18) alkyl dimethyl ammonium chloride.In another embodiment, quaternary ammonium salt includes, but are not limited to dicocoalkyl (C
12-C
18) two (the 2-hydroxyethyl coco alkyl (C of alkyl dimethyl ammonium chloride, two butter alkyl dimethyl ammonium chlorides, two (hydrogenated tallow alkyl) dimethyl-quaternary ammonium Methochloride, methyl
12-C
18) chlorination quaternary ammonium, dimethyl-(2-ethyl) butter ammonium methyl sulphate, dodecyl benzyl dimethyl ammonium chloride, Octadecane base benzyl dimethyl ammonium chloride, dodecyl trimethyl ammonium sulfate, soybean alkyl trimethyl ammonium chloride or hydrogenated tallow alkyl (2-ethylhexyl) dimethyl-quaternary ammonium Methylsulfate.
In one embodiment, there is about 15% weight of about 0.01-in catalyzer, based on oxalic dialdehyde weight.In another embodiment, there is about 10% weight of about 1-in catalyzer, based on oxalic dialdehyde weight.
Catalyzer can join the purified hydrocarbon stream simultaneously with oxalic dialdehyde, perhaps can separately add with oxalic dialdehyde.In one embodiment, before joining the purified hydrocarbon stream, with catalyzer and oxalic dialdehyde pre-mixing.
In order to make those skilled in the art can put into practice the disclosure better, by way of example the explanation mode rather than through the restriction mode provide following examples.
Embodiment
Embodiment 1
Oxalic dialdehyde is that pH is the compound based on water-based of about 2-about 3.When in the purified hydrocarbon stream, disperseing, its finally from the purified hydrocarbon stream sedimentation go out, become acid water, and be settled down to the bottom of processing units, cause corrosion.Reduce corrosive efficient in order to test corrosion inhibitor, in water, simulate corrosion test.
Two Carbon C1010 steel test buttons are weighed, and add to two spindles that in the 800ml autoclave, are installed on the stir shaft.Test button becomes 180 ° each other.Stir shaft is placed in the water, and under the rotations per minute shown in the table 1, stirs.Rotations per minute is used to calculate through the roughly flow velocity of pipeline and is shown in table 1.At room temperature, with the amount that is shown in table 1 corrosion inhibitor is added to the water.After 15 minutes, oxalic dialdehyde is injected in the water with the amount that is shown in table 1.With the autoclave sealing, heat water to about 180 ℉, with the temperature of simulation typical purified hydrocarbon stream during processing.After 4 hours, make even all the corrosion of test test button through any weight loss of measurement test button and with test button.
Table 1
1Used oxalic dialdehyde contains 2% weight quaternary ammonium catalyzer, and can be used as the commercially available GE of the deriving from Water of S-1750.
25K15 is water-soluble corrosion inhibitor, can be used as Philmplus
TMThe 5K 15 commercially available GE Water that derive from.
35K1642 is organic-solubility corrosion inhibitor, can be used as Philmplus
TM5K 1642 is commercially available to derive from GE Water, and contains the oleic acid pyrimidine of 3: 1 weight and the blend of dipolymer/trimer acid.
Compare with blank (sample CE-1), the organic soluble corrosion inhibitor shows significantly reduction corrosion.Tested water-soluble corrosion inhibitor (sample CE-2), but in fact it increase corrosion.
Embodiment 2
The organic soluble corrosion inhibitor is carried out other corrosion test, and in water, carry out according to embodiment 1.The result is shown in table 2.
Table 2
1Used oxalic dialdehyde contains the quaternary ammonium catalyzer of 2% weight, and can be used as the commercially available GE of the deriving from Water of S-1750.
2Can be used as Philmplus
TMThe 5K 1642 commercially available GE Water that derive from.
3Can be used as Sylvadym
The commercially available Sylvachem Corp that derives from of T-18.
4Can be used as the commercially available GE of the deriving from Water of CI-11C.
5Can be used as the commercially available GE of the deriving from Water of 5K2S.
6Can be used as the commercially available GE of the deriving from Water of 5K7.
Compare with blank (sample CE-3) and compare with organic soluble dipolymer/trimer acid (sample CE-4), the organic soluble corrosion inhibitor in sample 1-5 shows improved erosion resistance.
Embodiment 3
In the 800ml autoclave, test corrosion experiment and hydrogen sulfide are removed in the mixture of oily G&W.Gas oil is admixture H when beginning
2The about 0.5% weight solution of S in kerosene mixes with water subsequently.Two Carbon C1010 steel test buttons are weighed, and add to two spindles that are installed on the stir shaft.Test button becomes 180 ° each other.Stir shaft is placed in gas oil and the water mixture, and stirs down in 300rpm.The mixture of oil G&W is 200ml gas oil and 400ml water.Water: 2: 1 volume ratios of gas oil guarantee that sample always is immersed in the water under 300rpm, with the corrosion of test aqueous phase.At room temperature, with the amount that is shown in table 3 corrosion inhibitor is joined in the gas oil mixture.After 15 minutes, oxalic dialdehyde is injected in the gas oil mixture with the amount that is shown in table 3.With the autoclave sealing, gas oil and water mixture are heated to about 180 ℉, to simulate typical processing temperature.After 4 hours,, test button is made even all, and calculate mils per year (MPY), test the corrosion of test button through measuring any weight loss of test button.
Use ASTM 5705-95 test the carrying out hydrogen sulfide of revising to test, this test uses the Drager pipe handling (140 ℉) measurement in back 2 hours gas phase H
2S.Final H
2The S concentration measurement is shown in table 3.
Table 3
1Used oxalic dialdehyde contains the quaternary ammonium catalyzer of 2% weight, and can be used as the commercially available GE of the deriving from Water of S-1750.
2Can be used as Philmplus
TMThe 5K 1642 commercially available GE Water that derive from.
Compare with blank (sample CE-5), two samples (CE-5 and 1) all show removes hydrogen sulfide, and sample 1 also shows significantly reduction corrosion simultaneously.
Though illustrative purposes has been described typical embodiment for example, aforementioned description should not thought the restriction to this paper scope.Therefore, under the situation of spirit that does not depart from this paper and scope, those skilled in the art can expect various variants, reorganization and alternatives.
Claims (24)
1. the amount that is used for reducing the hydrogen sulfide that is present in the purified hydrocarbon stream with reduce the processing units that contacts this purified hydrocarbon stream in the method for corrosive amount; Said method comprises: in the purified hydrocarbon stream that contacts with processing units, add corrosion inhibitor with the protection processing units; With to purified hydrocarbon stream that shielded processing units contacts in add oxalic dialdehyde, wherein said corrosion inhibitor comprises and has the organic soluble compound that contains azo-cycle.
2. the process of claim 1 wherein that said purified hydrocarbon stream is selected from gas oil, petroleum naphtha, FCC slurry oil, diesel-fuel, oil fuel, jet fuel, gasoline, kerosene and vacuum residuum.
3. the process of claim 1 wherein that said purified hydrocarbon stream at elevated temperatures.
4. the method for claim 3, wherein said purified hydrocarbon stream is under about envrionment temperature to about 150 ℃ temperature.
5. the process of claim 1 wherein that said processing units is pipeline or storage tank.
6. the method for claim 5, wherein said processing units is processed by carbon steel.
7. the process of claim 1 wherein that said corrosion inhibitor comprises five yuan or the hexa-atomic azo-cycle that contains.
8. the method for claim 7, wherein corrosion inhibitor is an imidazolidine derivatives.
9. the method for claim 8, wherein said corrosion inhibitor is the fatty acid imidazoline quinoline.
10. the method for claim 8, wherein said fatty acid imidazoline quinoline has following structure:
Wherein R and R ' are C independently of one another
6-C
36Alkyl, thiazolinyl or aromatic group.
11. the method for claim 7, the wherein said azo-cycle that contains is a pyrimidine derivatives.
12. the method for claim 11, wherein said pyrimidine derivatives are the lipid acid pyrimidine.
13. the method for claim 12, wherein said lipid acid pyrimidine has following structure:
R wherein
aAnd R
bBe C independently of one another
6-C
36Alkyl, thiazolinyl or aromatic group.
14. the process of claim 1 wherein said corrosion inhibitor is injected in the purified hydrocarbon stream.
15. the process of claim 1 wherein that there is about 2ppm volume-Yue 100ppm volume in said corrosion inhibitor, based on the volume of said purified hydrocarbon stream.
16. the process of claim 1 wherein that said corrosion inhibitor provides protective coating on said processing units after said corrosion inhibitor being added in the purified hydrocarbon stream that contacts with processing units at least about 5 minutes.
17. the amount with the about 3000ppm volume of about 1ppm-that the process of claim 1 wherein joins the purified hydrocarbon stream with oxalic dialdehyde, based on the volume of said purified hydrocarbon stream.
18. the process of claim 1 wherein after adding oxalic dialdehyde, continue in said purified hydrocarbon stream, to add said corrosion inhibitor.
19. the method for claim 18, wherein the amount with about 1ppm volume-Yue 20ppm volume continues to add said corrosion inhibitor, based on the volume of said purified hydrocarbon stream.
20. the process of claim 1 wherein that said oxalic dialdehyde further comprises catalyzer.
21. the method for claim 20, wherein said catalyzer are quaternary ammonium salt.
22. the method for claim 21, wherein said catalyzer has formula I:
R
1R
2R
3R
4N
+X
- I
R wherein
1, R
2, R
3And R
4Independently of one another for alkyl with 1-30 carbon atom, have the aryl of 6-30 carbon atom or have the arylalkyl of 7-30 carbon atom; With X be halide-ions, sulfate radical, nitrate radical or carboxylate radical.
23. the method for claim 22, wherein said quaternary ammonium salt are alkyl benzyl ammonium chloride or benzyl cocounut oil alkyl (C
12-C
18) alkyl dimethyl ammonium chloride.
24. the method for claim 21, there is about 15% weight of about 0.01-in wherein said catalyzer, based on oxalic dialdehyde weight.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US12/535252 | 2009-08-04 | ||
| US12/535,252 US20110031165A1 (en) | 2009-08-04 | 2009-08-04 | Processes for removing hydrogen sulfide from refined hydrocarbon streams |
| PCT/US2010/040871 WO2011016935A2 (en) | 2009-08-04 | 2010-07-02 | Processes for removing hydrogen sulfide from refined hydrocarbo streams |
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| US (1) | US20110031165A1 (en) |
| EP (1) | EP2462207A2 (en) |
| JP (1) | JP2013501126A (en) |
| KR (1) | KR20120055582A (en) |
| CN (1) | CN102549114A (en) |
| AU (1) | AU2010281621A1 (en) |
| BR (1) | BR112012002528A2 (en) |
| CA (1) | CA2770008A1 (en) |
| MX (1) | MX2012001530A (en) |
| RU (1) | RU2012103702A (en) |
| SG (1) | SG178245A1 (en) |
| WO (1) | WO2011016935A2 (en) |
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| KR101293268B1 (en) | 2011-04-14 | 2013-08-16 | 한국화학연구원 | Corrosion Inhibitors Comprising Vegetable based Imidazoline Derivatives |
| WO2013049027A1 (en) * | 2011-09-27 | 2013-04-04 | General Electric Company | Hydrogen sulfide scavenger compositions, methods for making and processes for removing hydrogen sulfide from liquid hydrocarbon media |
| EP2951149B1 (en) | 2013-01-30 | 2018-10-10 | Ecolab USA Inc. | Hydrogen sulfide scavengers |
| CA2975910A1 (en) * | 2015-02-04 | 2016-08-11 | Ecolab Usa Inc. | Diphenyliodonium salts as sulfidogenesis inhibitors and antimicrobials |
| CA2982407C (en) | 2015-04-22 | 2022-03-15 | Ecolab Usa Inc. | Development of a high temperature stable scavenger for removal of hydrogen sulfide |
| MX2018002838A (en) * | 2015-09-08 | 2018-06-15 | Ecolab Usa Inc | Hydrocarbon soluble/dispersible hemiformals as hydrogen sulfide scavengers. |
| CA2997416C (en) * | 2015-09-08 | 2023-06-27 | Ecolab Usa Inc. | Hydrogen sulfide scavengers |
| CA3010550C (en) * | 2016-01-05 | 2021-06-22 | Dorf Ketal Chemicals (India) Private Limited | Hydrogen sulfide scavenging additive composition and method of use thereof. |
| WO2018022841A1 (en) | 2016-07-29 | 2018-02-01 | Ecolab Usa Inc. | Antifouling and hydrogen sulfide scavenging compositions |
| US10301553B2 (en) | 2017-02-28 | 2019-05-28 | Ecolab Usa Inc. | Use of sulfonium salts as hydrogen sulfide inhibitors |
| CA3069435A1 (en) | 2017-07-13 | 2019-01-17 | Ecolab Usa Inc. | Method of removing a sulfur containing compound by adding a composition |
| US10900128B2 (en) | 2018-08-29 | 2021-01-26 | Championx Usa Inc. | Use of sulfonium salts as corrosion inhibitors |
| CA3127439A1 (en) | 2019-01-23 | 2020-07-30 | Championx Usa Inc. | Complete removal of solids during hydrogen sulfide scavenging operations using a scavenger and a michael acceptor |
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- 2010-07-02 MX MX2012001530A patent/MX2012001530A/en not_active Application Discontinuation
- 2010-07-02 AU AU2010281621A patent/AU2010281621A1/en not_active Abandoned
- 2010-07-02 WO PCT/US2010/040871 patent/WO2011016935A2/en active Application Filing
- 2010-07-02 KR KR1020127005619A patent/KR20120055582A/en not_active Application Discontinuation
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- 2010-07-02 RU RU2012103702/04A patent/RU2012103702A/en not_active Application Discontinuation
- 2010-07-02 BR BR112012002528A patent/BR112012002528A2/en not_active IP Right Cessation
- 2010-07-02 EP EP10734605A patent/EP2462207A2/en not_active Withdrawn
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Also Published As
| Publication number | Publication date |
|---|---|
| MX2012001530A (en) | 2012-05-08 |
| SG178245A1 (en) | 2012-03-29 |
| AU2010281621A1 (en) | 2012-02-23 |
| EP2462207A2 (en) | 2012-06-13 |
| BR112012002528A2 (en) | 2019-09-24 |
| WO2011016935A2 (en) | 2011-02-10 |
| WO2011016935A3 (en) | 2012-04-12 |
| US20110031165A1 (en) | 2011-02-10 |
| RU2012103702A (en) | 2013-09-10 |
| JP2013501126A (en) | 2013-01-10 |
| KR20120055582A (en) | 2012-05-31 |
| CA2770008A1 (en) | 2011-02-10 |
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