WO2004044266A1 - Metal corrosion inhibitor and hydrogen chloride formation inhibitor in a crude oil atmospheric distillation unit - Google Patents

Metal corrosion inhibitor and hydrogen chloride formation inhibitor in a crude oil atmospheric distillation unit Download PDF

Info

Publication number
WO2004044266A1
WO2004044266A1 PCT/JP2003/014392 JP0314392W WO2004044266A1 WO 2004044266 A1 WO2004044266 A1 WO 2004044266A1 JP 0314392 W JP0314392 W JP 0314392W WO 2004044266 A1 WO2004044266 A1 WO 2004044266A1
Authority
WO
WIPO (PCT)
Prior art keywords
crude oil
hydrogen chloride
atmospheric distillation
metal
quaternary ammonium
Prior art date
Application number
PCT/JP2003/014392
Other languages
French (fr)
Inventor
Masakazu Koizumi
Tsuyoshi Hagiwara
Koichi Tanaka
Original Assignee
Kurita Water 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 Kurita Water Industries Ltd. filed Critical Kurita Water Industries Ltd.
Priority to EP03772720A priority Critical patent/EP1579033B1/en
Priority to US10/533,910 priority patent/US8177962B2/en
Priority to AU2003279571A priority patent/AU2003279571A1/en
Publication of WO2004044266A1 publication Critical patent/WO2004044266A1/en

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
    • C23F—NON-MECHANICAL REMOVAL OF METALLIC MATERIAL FROM SURFACE; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL; MULTI-STEP PROCESSES FOR SURFACE TREATMENT OF METALLIC MATERIAL INVOLVING AT LEAST ONE PROCESS PROVIDED FOR IN CLASS C23 AND AT LEAST ONE PROCESS COVERED BY SUBCLASS C21D OR C22F OR CLASS C25
    • C23F11/00—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent
    • C23F11/08—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids
    • C23F11/10—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
    • C23F11/14—Nitrogen-containing compounds
    • C23F11/141—Amines; Quaternary ammonium compounds
    • C—CHEMISTRY; METALLURGY
    • C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
    • C23F—NON-MECHANICAL REMOVAL OF METALLIC MATERIAL FROM SURFACE; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL; MULTI-STEP PROCESSES FOR SURFACE TREATMENT OF METALLIC MATERIAL INVOLVING AT LEAST ONE PROCESS PROVIDED FOR IN CLASS C23 AND AT LEAST ONE PROCESS COVERED BY SUBCLASS C21D OR C22F OR CLASS C25
    • C23F11/00—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent
    • C—CHEMISTRY; METALLURGY
    • C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02F5/00—Softening water; Preventing scale; Adding scale preventatives or scale removers to water, e.g. adding sequestering agents
    • C02F5/08—Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents
    • C02F5/10—Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents using organic substances
    • C02F5/12—Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents using organic substances containing nitrogen
    • C—CHEMISTRY; METALLURGY
    • C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02F5/00—Softening water; Preventing scale; Adding scale preventatives or scale removers to water, e.g. adding sequestering agents
    • C02F5/08—Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents
    • C02F5/10—Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents using organic substances
    • C02F5/12—Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents using organic substances containing nitrogen
    • C02F5/125—Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents using organic substances containing nitrogen combined with inorganic substances
    • 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
    • C10G7/00—Distillation of hydrocarbon oils
    • C10G7/10—Inhibiting corrosion during distillation
    • 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
    • C—CHEMISTRY; METALLURGY
    • C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
    • C23F—NON-MECHANICAL REMOVAL OF METALLIC MATERIAL FROM SURFACE; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL; MULTI-STEP PROCESSES FOR SURFACE TREATMENT OF METALLIC MATERIAL INVOLVING AT LEAST ONE PROCESS PROVIDED FOR IN CLASS C23 AND AT LEAST ONE PROCESS COVERED BY SUBCLASS C21D OR C22F OR CLASS C25
    • C23F11/00—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent
    • C23F11/04—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in markedly acid liquids
    • C—CHEMISTRY; METALLURGY
    • C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
    • C23F—NON-MECHANICAL REMOVAL OF METALLIC MATERIAL FROM SURFACE; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL; MULTI-STEP PROCESSES FOR SURFACE TREATMENT OF METALLIC MATERIAL INVOLVING AT LEAST ONE PROCESS PROVIDED FOR IN CLASS C23 AND AT LEAST ONE PROCESS COVERED BY SUBCLASS C21D OR C22F OR CLASS C25
    • C23F11/00—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent
    • C23F11/08—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids
    • C23F11/10—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
    • C—CHEMISTRY; METALLURGY
    • C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
    • C23F—NON-MECHANICAL REMOVAL OF METALLIC MATERIAL FROM SURFACE; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL; MULTI-STEP PROCESSES FOR SURFACE TREATMENT OF METALLIC MATERIAL INVOLVING AT LEAST ONE PROCESS PROVIDED FOR IN CLASS C23 AND AT LEAST ONE PROCESS COVERED BY SUBCLASS C21D OR C22F OR CLASS C25
    • C23F11/00—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent
    • C23F11/08—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids
    • C23F11/10—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
    • C23F11/14—Nitrogen-containing compounds
    • C—CHEMISTRY; METALLURGY
    • C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
    • C23F—NON-MECHANICAL REMOVAL OF METALLIC MATERIAL FROM SURFACE; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL; MULTI-STEP PROCESSES FOR SURFACE TREATMENT OF METALLIC MATERIAL INVOLVING AT LEAST ONE PROCESS PROVIDED FOR IN CLASS C23 AND AT LEAST ONE PROCESS COVERED BY SUBCLASS C21D OR C22F OR CLASS C25
    • C23F11/00—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent
    • C23F11/08—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids
    • C23F11/10—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
    • C23F11/14—Nitrogen-containing compounds
    • C23F11/141—Amines; Quaternary ammonium compounds
    • C23F11/142—Hydroxy amines
    • C—CHEMISTRY; METALLURGY
    • C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
    • C23F—NON-MECHANICAL REMOVAL OF METALLIC MATERIAL FROM SURFACE; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL; MULTI-STEP PROCESSES FOR SURFACE TREATMENT OF METALLIC MATERIAL INVOLVING AT LEAST ONE PROCESS PROVIDED FOR IN CLASS C23 AND AT LEAST ONE PROCESS COVERED BY SUBCLASS C21D OR C22F OR CLASS C25
    • C23F14/00—Inhibiting incrustation in apparatus for heating liquids for physical or chemical purposes
    • C23F14/02—Inhibiting incrustation in apparatus for heating liquids for physical or chemical purposes by chemical means
    • C—CHEMISTRY; METALLURGY
    • C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
    • C02F2303/00—Specific treatment goals
    • C02F2303/08—Corrosion inhibition
    • 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
    • C10G2300/1033—Oil well production fluids
    • 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
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
    • Y10S—TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y10S585/00—Chemistry of hydrocarbon compounds
    • Y10S585/949—Miscellaneous considerations
    • Y10S585/95—Prevention or removal of corrosion or solid deposits

Definitions

  • the present invention relates to a metal corrosion inhibitor for preventing corrosion of metal in a steam generating unit such as a boiler, steam generator or the like, or in a petroleum refining or petrochemical process unit, and to a method for preventing corrosion of metal in a steam generating unit or petroleum refining or petrochemical process unit, and relates in particular to a metal corrosion inhibitor and method for preventing corrosion of metal which can prevent corrosion even when small quantities of the metal corrosion inhibitor are added.
  • the present invention relates to a hydrogen chloride formation inhibitor and method for inhibiting formation of hydrogen chloride which can prevent metal corrosion caused by hydrogen chloride gas in a crude oil atmospheric distillation unit.
  • the steam generation unit of a process system may become contaminated with acid components including inorganic acid and organic acid derived from the process. Such acid components lower the pH at various points and cause corrosion.
  • Such corrosion can be prevented by neutralizing the acid components with a pH controller to obtain an appropriate pH.
  • ammonia and neutralizing amines are ordinarily used as pH controllers in feed water systems and vapor/condensed water systems.
  • neutralizing amines include alkanolamines, cyclohexylamine, morpholine and the like.
  • Corrosion prevention in the boiler is normally achieved by controlling the pH using boiler compounds containing sodium hydroxide, sodium phosphate or the like, but when volatile treatments are also being processed in the boiler, ammonia and neutralizing amines are used as pH controllers.
  • possible neutralizing amines include alkanolamines, cyclohexylamine, morpholine and the like (see Japanese Patent Application Laid-open No. S61-34095, page 2, upper left column, lines 1-3) .
  • hydrogen chloride, hydrogen sulfide, carbon dioxide and other acid components contained in the crude oil can dissolve in water (condensed water, free water, etc.) generated within or at the top of a distillation column or fractionating column or the like, and cause corrosion of the metal of the unit.
  • the crude oil is ordinarily first desalted in the desaltor, then heated to a prescribed temperature in the heating furnace and feeded to the atmospheric distillation column (main distillation column) , where it is separated into naphtha fraction, kerosene, gas oil component, residue and the like.
  • the magnesium chloride and calcium chloride in the crude oil produce hydrogen chloride gas by hydrolysis, as shown by the following reaction formula.
  • the hydrogen chloride gas produced in this way dissolves in condensed water produced in the low temperature area of the top of the column, the overhead system or the like of the atmospheric distillation column to form hydrochloric acid, leading to unpreferable results including acid corrosion of the metal of the unit.
  • pH controllers It is also necessary in the fields of petroleum refining and petrochemical process to control the pH in order to prevent corrosion of metal of the unit by acid components, and in general ammonia and neutralizing amines are used as pH controllers.
  • neutralizing amines include alkanolamines, methoxypropylamine and the like (see Japanese Patent Application Laid-open No. HlO-251639, page 2, left column, lines 12-24 and right column, lines 29-37) .
  • ammonia and neutralizing amines used as pH controllers as described above were only weakly neutralizing, and had to be added in large quantities. Such problems were particularly obvious when trying to prevent corrosion inside a boiler if volatile treatment was being processed.
  • the present invention first provides a metal corrosion inhibitor for preventing corrosion of metal in a steam generating unit or petroleum refining or petrochemical process unit comprising a quaternary ammonium compound described by general formula [1] below:
  • steam generating unit signifies a unit capable of generating steam, and the metal composing such unit may undergo corrosion.
  • Petroleum refining or petrochemical process unit signifies a unit used in petroleum refining process or petrochemical process, and the metal composing such unit may undergo corrosion, with no limits on the type of process in petroleum refining or petrochemical process.
  • R 1 , R 2 and R 3 in the general formula [1] be the same or different hydrocarbon radicals with 1-3 carbon atoms, and that n be an integer between 1 and 4 (Invention 2), and it is particularly preferable that the quaternary ammonium
  • the present invention provides a method for preventing corrosion of metal in a steam generating unit, wherein the quaternary ammonium compound described by general formula [1] below:
  • the quaternary ammonium compound described by general formula [1] above be added in the range of 0.1-50 mg/L to feed water which may contact the inside of the steam generating unit (Invention 6) .
  • the present invention provides a method for preventing corrosion of metal in a petroleum refining or petrochemical process unit, wherein the quaternary ammonium compound described by general formula [1] below:
  • the present invention provides a method for preventing corrosion of metal in an atmospheric distillation column for petroleum refining process, wherein a quaternary ammonium compound described by General Formula [1] below:
  • R 1 , R 2 and R 3 are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10.
  • quaternary ammonium compound A (wherein R 1 , R 2 and R are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10) (sometimes referred to hereunder as "quaternary ammonium compound A) has a higher degree of dissociation than the ammonia and neutralizing amines conventionally used as pH controllers, its capability to raise pH in water is high (its basic is strong) . Moreover, because quaternary ammonium compound A has relatively low volatility, it is likely to remain in the system to which quaternary ammonium compound A was added. Consequently, with quaternary ammonium compound A it is possible to effectively prevent corrosion of metal even if only a small quantity is added.
  • quaternary ammonium compound A is strongly basic, neutralized salts formed by quaternary ammonium compound A with acids can maintain a higher pH than conventional amine salts even when dissolved in water. Consequently, not only does quaternary ammonium compound A only need to be added in small quantities, but it greatly reduces the risk of secondary corrosion caused by neutralized salts.
  • the present invention provides a hydrogen chloride formation inhibitor for a crude oil atmospheric
  • distillation unit comprising ( ⁇ - hydroxyethyl) trimethylammonium hydroxide (Invention 9).
  • ( ⁇ - hydroxyethyl) trimethylammonium hydroxide it is preferable that ( ⁇ - hydroxyethyl) trimethylammonium hydroxide be contained in an amount of 5% by mass or more (Invention 10) .
  • the present invention provides a method for inhibiting formation of hydrogen chloride in a crude oil atmospheric distillation unit, wherein ( ⁇ - hydroxyethyl) trimethylammonium hydroxide is contained in the desalted crude oil in between the crude oil desaltor and the main distillation column in the crude oil atmospheric distillation unit (Invention 11) .
  • crude oil atmospheric distillation unit signifies a unit involved in atmospheric distillation in crude oil refining process, and includes a crude oil desaltor, a pre-distillation column if such exists, a furnace, a main distillation column (atmospheric distillation column) , a heat exchanger, a condenser, a receiving tank and any associated piping and the like.
  • choline in the crude oil atmospheric distillation unit, it is possible to prevent the formation of the hydrogen chloride itself, thus preventing corrosion of the metal of the unit due to hydrogen chloride. Because the choline used here does not contain any metals which might adversely affect catalyst in the heavy oil direct desulfurization unit or the like, the choline will not lead to deterioration of the catalyst even if added in excess.
  • the choline chlorides produced in this way will be decomposed by heat in the furnace, but the main decomposition products will be methyl chloride and amines such as trimethylamine and N,N-dimethylaminoethanol, with almost no hydrogen chloride produced. Moreover, because the choline chloride is more fluid than the hydrochlorides of alkanolamines ordinarily used as neutralizers, and its metal corrosiveness is extremely low, it will not cause corrosion of the metal of the unit or line blockage.
  • the ( ⁇ -hydroxyethyl) trimethylammonium hydroxide content be controlled to 0.1-5 times by molar equivalent the salts content in the desalted crude oil (Invention 12) .
  • sources of hydrogen chloride formation such as magnesium chloride and calcium chloride can be easily converted efficiently and economically to choline chloride.
  • problems hardly arise.
  • the ( ⁇ -hydroxyethyl) trimethylammonium hydroxide content be controlled such that the chloride ion concentration (sodium chloride conversion) of the overhead receiver water is 0-30 mg/L or the pH of the overhead receiver water is 5.5-7.0 (Invention 14).
  • Figure 1 is a schematic diagram of one example of a boiler
  • Figure 2 is a process drawing of one example of a crude oil atmospheric distillation method (2-columns type) ;
  • Figure 3 shows a chart of the GC/MS measurement results for thermal decomposition of choline chloride.
  • the metal corrosion inhibitor of the present invention contains the quaternary ammonium compound (quaternary ammonium compound A) described by general formula [1] below:
  • R 1 , R 2 and R 3 are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10.
  • hydrocarbon radicals with 1 to 4 carbon atoms in general formula [1] include methyl, ethyl, n-propyl, isopropyl, n-butyl, isobutyl, sec-butyl, t-butyl and other straight-chain or branched-chain alkyl radicals .
  • quaternary ammonium compound A include hydroxymethyltrimethylammonium hydroxide, hydroxymethyltriethylammonium hydroxide, (2- hydroxyethyl) triethylammonium hydroxide and (3- hydroxypropyl ) trimethylammonium hydroxide .
  • R 1 , R 2 and R 3 be the same or different hydrocarbon radicals with 1-3 carbon atoms, and that n be an integer between 1 and 4.
  • quaternary ammonium compound A is highly soluble in water, enhancing the effect of the present invention in preventing corrosion even when
  • the metal corrosion inhibitor of the present invention can be composed entirely of quaternary ammonium compound A, but may also contain ammonia, neutralizing amines and other corrosion inhibitors, hydrazine, sodium sulfite, sugars and other oxygen scavengers and the like in addition of quaternary ammonium compound A.
  • quaternary ammonium compound A in the metal corrosion inhibitor of the present invention so long as the effect of the present invention is achieved to prevent corrosion even when small quantities are added.
  • a content of 1-100% by mass is normal, and 5-50% by mass is preferable.
  • the metal corrosion inhibitor of the present invention examples include for example iron, iron alloys, copper, copper alloys, aluminized steel and the like, but the present invention is not limited by these.
  • the metal corrosion inhibitor of the present invention can prevent corrosion of unit metals in steam generating units and petroleum refining and petrochemical process by methods such as those described below.
  • the steam generating unit which is to be protected from corrosion is a unit which is capable of generating steam, such as a general boiler, the waste heat boiler of a petrochemical plant, gas turbine facility or the like, or the steam generator of a pressurized water reactor or the like, and which is liable to corrosion of the metal of the unit.
  • the boiler may be a cylindrical boiler, water tube boiler, once-through boiler, cast-iron boiler or special boiler (indirect heating boiler, waste heat boiler, special fuel boiler, special fluid boiler or the like) .
  • the metal corrosion inhibitor or quaternary ammonium compound A of the present invention is added to water which may contact the inside of the steam generating unit, and undergoes a neutralizing reaction with acids in the water.
  • the steam generating unit is a boiler there are three water systems (the feed water system, the inside of the boiler and the vapor/condensed water system)
  • the metal corrosion inhibitor or quaternary ammonium compound A of the present invention can be added to any one or more than one of these water systems.
  • neutralization is more widespread if the metal corrosion inhibitor or quaternary ammonium compound A of the present invention is added further upstream, it is generally preferable to add it to the feed water system.
  • the method for adding the metal corrosion inhibitor or quaternary ammonium compound A of the present invention to the water system may be continuous injection or intermittent injection.
  • continuous injection either quantified injection or flow rate proportional injection may be used, while in the case of intermittent injection, either suction injection or forcing injection may be used.
  • the quantity of the metal corrosion inhibitor or quaternary ammonium compound A of the present invention added to the water system will differ depending on pressures of boiler, processing methods and the like and cannot be decided definitely, but should be in the range of 0.1-50 mg/L or more preferably 0.2-10 mg/L with respect to the feed water. Practically, it can be controlled as necessary to meet required standards of water quality: for example, the pH of boiler water with a maximum use pressure of 10.0 MPa and with a volatile treatment should be controlled to 8.5- 9.5, in which case the quantity of the metal corrosion inhibitor or quaternary ammonium compound A of the present invention added should be 0.4-4 mg/L with respect to the feed water.
  • quaternary ammonium compound A has a high degree of dissociation and is strongly neutralizing in comparison with the ammonia and neutralizing amines used as conventional pH controllers, and it is also likely to remain in the boiler due to its relatively low volatility, it can efficiently prevent corrosion even when added in small quantities. Consequently, by adding the metal corrosion inhibitor or quaternary ammonium compound A of the present invention to a water system, especially to a feed water system, it is possible to efficiently neutralize and prevent corrosion in the feed water, the boiler and the vapor/condensed water system.
  • amines have conventionally been used in large quantities to control pH, but using the metal corrosion inhibitor or quaternary ammonium compound A of the present invention as a pH controller in such steam generating units, adequate corrosion prevention can be achieved with the addition of only small quantities.
  • quaternary ammonium compound A is strongly basic, it can maintain a higher pH than conventional amine salts even when amine carbonates produced by neutralization become dissolved in water. That is, with the present invention it is possible to effectively prevent secondary corrosion caused by neutralized salts. [A method for preventing corrosion of metal in petroleum refining and petrochemical process units]
  • corrosion of metal in a petroleum refining process unit or petrochemical process unit is prevented through the use of the aforementioned metal corrosion inhibitor or quaternary ammonium compound A. of the present invention.
  • corrosion of the metal of units is especially likely to occur in the BTX refining process, ethylene manufacturing process, styrene monomer manufacturing process and the like.
  • units to be protected from corrosion including units liable to corrosion by acids, such as the atmospheric distillation column and fractionating column and their attached connecting pipes, condensers, heat exchangers, receiving tanks and other units .
  • the metal corrosion inhibitor or quaternary ammonium compound A of the present invention is contained in fluids (oil, water, other liquids or gases) which may contact the inside of the petroleum refining or petrochemical process unit, and undergoes a neutralizing reaction with acids in the fluid.
  • fluids oil, water, other liquids or gases
  • it can be added either through the side reflux line or directly into the column, or else into the feed line of the column.
  • pH within the overhead condenser of a column it should be added to the ejection pipe at the top of the column.
  • the method for adding the metal corrosion inhibitor or quaternary ammonium compound A of the present invention to a fluid may be continuous injection or intermittent injection. In the case of continuous injection, either quantified injection or flow rate proportional injection may be used.
  • the quantity of the metal corrosion inhibitor or quaternary ammonium compound A of the present invention added to the fluid may be controlled appropriately such that the pH in the system is within a range which is unlikely to cause corrosion of metal of the unit. For example in the top line of a crude oil atmospheric distillation column, it should be controlled to achieve a pH of 5.5-6.5 within the system.
  • quaternary ammonium compound A is more strongly basic than ammonia and neutralizing amines as the conventional pH controllers, it can effectively prevent corrosion even when added in small quantities. Consequently, by adding the metal corrosion inhibitor or quaternary ammonium compound A of the present invention to fluid which may contact the inside of a petroleum refining or petrochemical process unit, it is possible to efficiently prevent corrosion of metals of the unit.
  • secondary corrosion can be restrained with quaternary ammonium compound A because it is less corrosive than hydrochlorides of the ammonia, alkanolamines, methoxypropylzmine and the like conventionally used as pH controllers.
  • hydrochlorides of the ammonia, alkanolamines, methoxypropylzmine and the like conventionally used as pH controllers.
  • greater corrosion prevention effects can be achieved with the present invention.
  • choline (hereunder called "choline") . It is preferable to use this hydrogen chloride formation inhibitor in the form of an aqueous solution of choline. In this case, choline should be contained in the hydrogen chloride formation inhibitor in the amount of about 5-100% by mass or preferably about 20- 50% by mass . If used according to the methods described below, the hydrogen chloride formation inhibitor of the present invention can prevent formation of hydrogen chloride and protect a crude oil atmospheric distillation unit from corrosion. When using the hydrogen chloride formation inhibitor of the present invention, alkaline chemicals such as sodium hydroxide can also be used in combination. [Hydrogen chloride formation inhibiting method]
  • hydrogen chloride formation is inhibited and corrosion of unit metal is prevented in a crude oil atmospheric distillation unit through the use of choline or the aforementioned hydrogen chloride formation inhibitor (both referred to hereunder as "the hydrogen chloride formation inhibitor.")
  • the hydrogen chloride formation inhibitor is preferably contained in the desalted crude oil between the crude oil desaltor and main distillation column of the crude oil atmospheric distillation unit, and more specifically it is preferably added to the desalted crude oil at the outlet of the crude oil desaltor.
  • the hydrogen chloride formation inhibitor is preferably added to the desalted crude oil being controlled such that the choline content of the hydrogen chloride formation inhibitor is 0.1-5 times or preferably 1-2 times by molar equivalent the salts content of magnesium chloride, calcium chloride and other salts in the desalted crude oil.
  • Continuous injection is the preferable method for adding the hydrogen chloride formation inhibitor (injection method), and in particular it is preferable to inject continuously while controlling the content of the hydrogen chloride formation inhibitor according to the salts content of the desalted crude oil.
  • the salts content of desalted crude oil fluctuates, but it is possible to appropriately control the quantity of hydrogen chloride formation inhibitor to be added by measuring the chloride ion concentration or pH of the top line of the main distillation column in the above way.
  • the quantity of hydrogen chloride formation inhibitor to be added be controlled such that the chloride ion concentration (sodium chloride conversion) of the overhead receiver water is 0-30 mg/L or more preferably 0-10 mg/L, or the pH of the overhead receiver water is 5.5-7.0 or more preferably 5.5-6.5.
  • the choline in the hydrogen chloride formation inhibitor has a high degree of dissociation and is strongly basic, it reacts with salts such as magnesium chloride, calcium chloride and the like in the desalted crude oil to produce choline chlorides, as shown by the following chemical formula:
  • the hydrogen chloride formation inhibitor by adding the hydrogen chloride formation inhibitor to desalted crude oil as described above, it is possible to prevent formation of the hydrogen chloride itself and corrosion of metal of the unit due to hydrogen chloride. Because the choline in the hydrogen chloride formation inhibitor does not contain any metals which might adversely affect catalyst in the heavy oil direct desulfurization unit or the like, deterioration of the catalyst will not result even if the hydrogen chloride formation inhibitor is added in excess.
  • the choline chlorides produced in this way will be decomposed by heating as shown in the following formula, but the main decomposition products will be methyl chloride and amines such as trimethylamine and N,N-dimethylaminoethanol, with almost no hydrogen chloride produced.
  • hydrochlorides of the alkanolamines normally used as neutralizers cause secondary corrosion because they are highly hygroscopic, and absorb water inside the system, dissolve and lower pH
  • choline chlorides are more fluid than hydrochlorides of alkanolamines, and have extremely low metal corrosiveness, so they do not cause problems such as corrosion of the unit metal or line blockage .
  • Crude oil is supplied continuously to crude oil desaltor 1, where it is desalted and dehydrated and solid matter is removed.
  • Desalted crude oil exiting crude oil desaltor 1 is feeded to pre-distillation column 3 through line 2, while the hydrogen chloride formation inhibitor is added to line 2 at the outlet of crude oil desaltor 1 and converts magnesium chloride and calcium chloride to choline chlorides.
  • Desalted crude oil to which the hydrogen chloride formation inhibitor has been added is feeded to pre-distillation column 3 through line 2, and evaporated water and light oil from the pre-distillation column 3 are supplied to main distillation column 7 through line 4.
  • Residue from pre-distillation column 3 is feeded to furnace 6 through line 5, heated to a prescribed temperature, then feeded to main distillation column 7, where it is fractionated into its various fractions (naphtha and kerosene, heavy kerosene, light gas oil, heavy gas oil and residue) .
  • the partial magnesium chloride and calcium chloride remaining is hydrolyzed and may produce hydrogen chloride, but the resulting hydrogen chloride is captured as choline' chloride by unreacted choline.
  • Naphtha and kerosene from the top of main distillation column 7 are condensed through line 8, and collected in naphtha/kerosene receiving tank 9 (an example of an overhead receiver) .
  • Gases and liquids are separated in this naphtha/kerosene receiving tank 9, and the fuel gas or LPG as the gas fraction is removed through line 10, while the naphtha and kerosene as the liquid fraction are removed through line 11.
  • the water (overhead receiver water) which accumulates at the bottom of naphtha/kerosene receiving tank 9 is drained through drain 12 of naphtha/kerosene receiving tank 9.
  • the chloride ion concentration or pH of the overhead receiver water drained from naphtha/kerosene receiving tank 9 is measured. Based on the measurement results, the quantity of hydrogen chloride formation inhibitor added to line 2 at the outlet of crude oil desaltor 1 is controlled appropriately.
  • the measurement of chloride ion concentration or pH and the control of quantity of hydrogen chloride formation inhibitor to be added can be automated as a sequential system.
  • the crude oil atmospheric distillation method described above uses an example of a 2-columns type, but the present invention is not limited thereby, and formation of hydrogen chloride can also be prevented by methods similar to those described above with a crude oil atmospheric distillation method using a different example of a 2-columns type, or with a crude oil atmospheric distillation method using a 1- column type .
  • Aqueous solutions containing magnesium chloride and basic material (choline, sodium hydroxide, monoethanolamine, dimethylethanolamine) at a mole ratio of 1:2 and an aqueous solution containing magnesium chloride alone without any basic material were prepared and used as test solutions 1-5.
  • the compositions of the test solutions (TS) are shown in Table 4. [Table 4 ]
  • the pH values of choline, monoethanolamine- and dimethylethanolamine were measured using a pH meter (manufactured by Horiba, product name pH Meter F-21) , and the respective base dissociation constants (Kb value, 25 °C and 170°C) were calculated. These base dissociation constants are an indicator of neutralizing capability, with a larger number indicating that the substance has a higher degree of dissociation and is more strongly basic. The results are shown in Table 6.
  • choline chloride produces methyl chloride, trimethylamine and N,N- dimethylaminoethanol by thermal decomposition, but does not produce hydrogen chloride.
  • the metal corrosion inhibitor of the present invention can adequately prevent corrosion of metal in a steam generating unit or petroleum refining or petrochemical process unit even when added in small quantities, and can reduce the risk of secondary corrosion because the neutralized salts produced do not dramatically lower pH when dissolved in water.
  • corrosion of metal in a steam generating unit or petroleum refining or petrochemical process unit can be adequately prevented when the quantity of chemical added is small, and the risk of secondary corrosion can be reduced because the resulting neutralized salts do not dramatically lower pH even when dissolved in water.
  • the metal corrosion inhibitor and method for preventing corrosion of metal of the present invention are useful for inhibiting metal corrosion in steam generating units and petroleum refining and petrochemical process units.
  • the hydrogen chloride formation inhibitor and method for inhibiting formation of hydrogen chloride of the present invention it is possible in a crude oil atmospheric distillation unit to prevent corrosion of the metal of the unit due to hydrogen chloride by inhibiting the formation of the hydrogen chloride itself.
  • the hydrogen chloride formation inhibitor and method for inhibiting formation of hydrogen chloride of the present invention do not adversely affect the catalyst in the heavy oil direct desulfurization unit, and there is no risk of metal corrosion or line blockage from salts produced by the hydrogen chloride formation inhibitor or method for inhibiting formation of hydrogen chloride of the present invention.
  • the hydrogen chloride formation inhibitor and method for inhibiting formation of hydrogen chloride of the present invention are useful in preventing the formation of hydrogen chloride in crude oil atmospheric distillation units.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Engineering & Computer Science (AREA)
  • Metallurgy (AREA)
  • Mechanical Engineering (AREA)
  • Materials Engineering (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Water Supply & Treatment (AREA)
  • Environmental & Geological Engineering (AREA)
  • Hydrology & Water Resources (AREA)
  • Inorganic Chemistry (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Preventing Corrosion Or Incrustation Of Metals (AREA)

Abstract

The quaternary ammonium compound described by general formula 1 below[general formula 1] (wherein R?1, R2 and R3¿ are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10) is used as a metal corrosion inhibitor. With this metal corrosion inhibitor, it is possible even with the addition of small quantities to adequately prevent corrosion of metal in a steam generating unit or petroleum refining or petrochemical process unit. Moreover, ($G(b)-hydroxyethyl)trimethylammonium hydroxide is used as a hydrogen chloride formation inhibitor for a crude oil atmospheric distillation unit. With this hydrogen chloride formation inhibitor, it is possible to prevent the formation of hydrogen chloride itself in a crude oil atmospheric distillation unit without having any adverse effect on the catalyst.

Description

DESCRIPTION
METAL CORROSION INHIBITOR AND HYDROGEN CHLORIDE FORMATION INHIBITOR IN A CRUDE OIL ATMOSPHERIC DISTILLATION UNIT
BACKGROUND OF THE INVENTION
1. Field of the Invention
The present invention relates to a metal corrosion inhibitor for preventing corrosion of metal in a steam generating unit such as a boiler, steam generator or the like, or in a petroleum refining or petrochemical process unit, and to a method for preventing corrosion of metal in a steam generating unit or petroleum refining or petrochemical process unit, and relates in particular to a metal corrosion inhibitor and method for preventing corrosion of metal which can prevent corrosion even when small quantities of the metal corrosion inhibitor are added. Moreover, the present invention relates to a hydrogen chloride formation inhibitor and method for inhibiting formation of hydrogen chloride which can prevent metal corrosion caused by hydrogen chloride gas in a crude oil atmospheric distillation unit.
2. Description of the Related Art
In order to prevent corrosion of metal in equipment such as various types of boilers, the waste heat boilers of petrochemical plants, gas turbine facilities and the like, and the steam generators of pressurized water reactors, it is necessary to control the pH appropriately at various points (the feed water system, the boiler, the vapor/condensed water system.) For example, in a boiler wherein softened water or raw water is feeded, carbonic acid is produced when carbonates and hydrogen carbonates contained in the feed water decompose in the boiler water. The resulting carbonic acid lowers the pH primarily in the vapor/condensed water system, and this causes corrosion.
Moreover, the steam generation unit of a process system may become contaminated with acid components including inorganic acid and organic acid derived from the process. Such acid components lower the pH at various points and cause corrosion.
Such corrosion can be prevented by neutralizing the acid components with a pH controller to obtain an appropriate pH.
Thus, ammonia and neutralizing amines are ordinarily used as pH controllers in feed water systems and vapor/condensed water systems. Examples of neutralizing amines include alkanolamines, cyclohexylamine, morpholine and the like. Corrosion prevention in the boiler is normally achieved by controlling the pH using boiler compounds containing sodium hydroxide, sodium phosphate or the like, but when volatile treatments are also being processed in the boiler, ammonia and neutralizing amines are used as pH controllers. As above, possible neutralizing amines include alkanolamines, cyclohexylamine, morpholine and the like (see Japanese Patent Application Laid-open No. S61-34095, page 2, upper left column, lines 1-3) .
In the fields of petroleum refining process and petrochemical process, hydrogen chloride, hydrogen sulfide, carbon dioxide and other acid components contained in the crude oil can dissolve in water (condensed water, free water, etc.) generated within or at the top of a distillation column or fractionating column or the like, and cause corrosion of the metal of the unit.
For example, in the atmospheric distillation process of petroleum refining, the crude oil is ordinarily first desalted in the desaltor, then heated to a prescribed temperature in the heating furnace and feeded to the atmospheric distillation column (main distillation column) , where it is separated into naphtha fraction, kerosene, gas oil component, residue and the like. In this atmospheric distillation process, the magnesium chloride and calcium chloride in the crude oil produce hydrogen chloride gas by hydrolysis, as shown by the following reaction formula.
CaCl2 + 2H20 (heating) --> Ca(OH)2 + 2HC1
MgCl2 + 2H20 (heating) —> Mg(OH)2 + 2HC1
The hydrogen chloride gas produced in this way dissolves in condensed water produced in the low temperature area of the top of the column, the overhead system or the like of the atmospheric distillation column to form hydrochloric acid, leading to unpreferable results including acid corrosion of the metal of the unit.
It is also necessary in the fields of petroleum refining and petrochemical process to control the pH in order to prevent corrosion of metal of the unit by acid components, and in general ammonia and neutralizing amines are used as pH controllers. Examples of neutralizing amines include alkanolamines, methoxypropylamine and the like (see Japanese Patent Application Laid-open No. HlO-251639, page 2, left column, lines 12-24 and right column, lines 29-37) .
In the atmospheric distillation process of petroleum refining, efforts are also made to prevent formation of the hydrogen chloride gas itself which is the cause of metal corrosion, with the following technologies being employed.
(1) A method of preventing formation of hydrogen chloride by adding sodium hydroxide to the crude oil at the desaltor outlet in order to convert the magnesium chloride and calcium chloride in the crude oil to stable (not hydrolyzing even when heated) sodium chloride.
(2) A method of neutralize the generated hydrogen chloride in the form of amine salts by adding alkanolamines to the crude oil at the desaltor outlet (Japanese Patent Application Laid-open No. H3-101801, Claims).
However, the ammonia and neutralizing amines used as pH controllers as described above were only weakly neutralizing, and had to be added in large quantities. Such problems were particularly obvious when trying to prevent corrosion inside a boiler if volatile treatment was being processed.
When used as pH controllers, moreover, ammonia and neutralizing amines produce acid components and salts during the neutralization process, and since ammonia and neutralizing amines are only weakly neutralizing, the resulting neutralized salts (amine hydrochlorides, amine carbonates and the like) and neutralized salts of strong acids in particular (such as amine hydrochlorides) can dramatically lower the pH when they dissolve in water, thus causing secondary corrosion.
On the other hand, in the above method (1) as a technology for inhibiting formation of hydrogen chloride, if too much sodium hydroxide was added, the sodium deteriorated catalysts in the heavy oil direct desulfurization unit at the subsequent stage. So it was necessary to limit the amount of sodium hydroxide added even if the crude oil at the desaltor outlet had a high salt concentration. As the result, the inhibitory effect on formation of hydrogen chloride was not satisfactory. In fact, when a crude oil refining unit was being operated continuously for two years or more, catalyst in the heavy oil direct desulfurization unit which had deteriorated due mainly to sodium from the sodium chloride had to be changed once a year.
In the above method (2), if the operating temperature of the top of the atmospheric distillation column was lower than the melting point of the amine hydrochlorides produced by neutralization, the amine hydrochlorides accumulated within the atmospheric distillation column, causing problems such as corrosion, line blockage or the like within the unit. Moreover, when the amine hydrochlorides produced by neutralization were heated by the furnace of the atmospheric distillation column, they became partially hydrolyzed, again producing hydrogen chloride. So neutralization by adding amines again to the top of the column was needed.
SUMMARY OF THE INVENTION With the foregoing in view, it is an object of the present invention to provide a metal corrosion inhibitor and method for preventing corrosion of metal capable of adequately preventing corrosion even when small quantities of the metal corrosion inhibitor are added, and capable of reducing the risk of secondary corrosion caused by generated neutralized salts. Moreover, it is an object of the present invention to provide a hydrogen chloride formation inhibitor and method for inhibiting formation of hydrogen chloride capable of preventing formation of the hydrogen chloride itself rather than neutralizing hydrogen chloride produced in a crude oil atmospheric distillation unit, without any deterioration of the catalyst.
In order to achieve the objects, the present invention first provides a metal corrosion inhibitor for preventing corrosion of metal in a steam generating unit or petroleum refining or petrochemical process unit comprising a quaternary ammonium compound described by general formula [1] below:
Figure imgf000009_0001
(wherein R1, R2 and R3 are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10) (Invention 1) .
In the present invention, "steam generating unit" signifies a unit capable of generating steam, and the metal composing such unit may undergo corrosion. "Petroleum refining or petrochemical process unit" signifies a unit used in petroleum refining process or petrochemical process, and the metal composing such unit may undergo corrosion, with no limits on the type of process in petroleum refining or petrochemical process.
In the metal corrosion inhibitor according to the invention (Invention 1) above, it is preferable that R1, R2 and R3 in the general formula [1] be the same or different hydrocarbon radicals with 1-3 carbon atoms, and that n be an integer between 1 and 4 (Invention 2), and it is particularly preferable that the quaternary ammonium
compound described by general formula [1] above be (β- hydroxyethyl) trimethylammonium hydroxide (Invention 3) . It is also preferable that the quaternary ammonium compound described by general formula [1] above be contained in the amount of 1% by mass or more (Invention 4) .
Second, the present invention provides a method for preventing corrosion of metal in a steam generating unit, wherein the quaternary ammonium compound described by general formula [1] below:
Figure imgf000011_0001
(wherein R1, R2 and R3 are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10) is contained in water which may contact the inside of the steam generating unit (Invention 5) .
In the aforementioned method • for preventing corrosion of metal (Invention 5) , it is preferable that the quaternary ammonium compound described by general formula [1] above be added in the range of 0.1-50 mg/L to feed water which may contact the inside of the steam generating unit (Invention 6) .
Third, the present invention provides a method for preventing corrosion of metal in a petroleum refining or petrochemical process unit, wherein the quaternary ammonium compound described by general formula [1] below:
R^—
Figure imgf000011_0002
(wherein R1, R2 and R3 are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10) is contained in fluid which may contact the inside of the petroleum refining or petrochemical process unit (Invention 7).
Fourth, the present invention provides a method for preventing corrosion of metal in an atmospheric distillation column for petroleum refining process, wherein a quaternary ammonium compound described by General Formula [1] below:
Figure imgf000012_0001
(in which R1, R2 and R3 are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10) is contained in fluid which may contact the inside of the atmospheric distillation column for petroleum refining process such that a pH value thereof at the top line of the atmospheric distillation column is 5.5- 6.5 (Invention 8) .
Regarding the above invention 1 to 8, because the quaternary ammonium compound described by general formula [1] below: R2— N — (C H 2)n -O H O H" R3
(wherein R1, R2 and R are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10) (sometimes referred to hereunder as "quaternary ammonium compound A) has a higher degree of dissociation than the ammonia and neutralizing amines conventionally used as pH controllers, its capability to raise pH in water is high (its basic is strong) . Moreover, because quaternary ammonium compound A has relatively low volatility, it is likely to remain in the system to which quaternary ammonium compound A was added. Consequently, with quaternary ammonium compound A it is possible to effectively prevent corrosion of metal even if only a small quantity is added.
In addition, because quaternary ammonium compound A is strongly basic, neutralized salts formed by quaternary ammonium compound A with acids can maintain a higher pH than conventional amine salts even when dissolved in water. Consequently, not only does quaternary ammonium compound A only need to be added in small quantities, but it greatly reduces the risk of secondary corrosion caused by neutralized salts.
Fifth, the present invention provides a hydrogen chloride formation inhibitor for a crude oil atmospheric
distillation unit, comprising (β- hydroxyethyl) trimethylammonium hydroxide (Invention 9).
In the aforementioned hydrogen chloride formation
inhibitor (Invention 9) , it is preferable that (β- hydroxyethyl) trimethylammonium hydroxide be contained in an amount of 5% by mass or more (Invention 10) .
Sixth, the present invention provides a method for inhibiting formation of hydrogen chloride in a crude oil atmospheric distillation unit, wherein (β- hydroxyethyl) trimethylammonium hydroxide is contained in the desalted crude oil in between the crude oil desaltor and the main distillation column in the crude oil atmospheric distillation unit (Invention 11) .
In the present invention "crude oil atmospheric distillation unit" signifies a unit involved in atmospheric distillation in crude oil refining process, and includes a crude oil desaltor, a pre-distillation column if such exists, a furnace, a main distillation column (atmospheric distillation column) , a heat exchanger, a condenser, a receiving tank and any associated piping and the like.
Because (β-hydroxyethyl) trimethylammonium hydroxide (also known as choline) has a high degree of dissociation and is strongly basic, the magnesium chloride and calcium chloride which cause hydrogen chloride formation can be
easily converted to hydrochlorides of (β- hydroxyethyl) trimethylammonium hydroxide (choline chlorides) .
That is, by using choline in the crude oil atmospheric distillation unit, it is possible to prevent the formation of the hydrogen chloride itself, thus preventing corrosion of the metal of the unit due to hydrogen chloride. Because the choline used here does not contain any metals which might adversely affect catalyst in the heavy oil direct desulfurization unit or the like, the choline will not lead to deterioration of the catalyst even if added in excess.
The choline chlorides produced in this way will be decomposed by heat in the furnace, but the main decomposition products will be methyl chloride and amines such as trimethylamine and N,N-dimethylaminoethanol, with almost no hydrogen chloride produced. Moreover, because the choline chloride is more fluid than the hydrochlorides of alkanolamines ordinarily used as neutralizers, and its metal corrosiveness is extremely low, it will not cause corrosion of the metal of the unit or line blockage.
In the aforementioned method for inhibiting formation of hydrogen chloride (Invention 11), it is preferable that
the (β-hydroxyethyl) trimethylammonium hydroxide content be controlled to 0.1-5 times by molar equivalent the salts content in the desalted crude oil (Invention 12) . With the choline content controlled in this way, sources of hydrogen chloride formation such as magnesium chloride and calcium chloride can be easily converted efficiently and economically to choline chloride. However, even if choline is contained in excess, problems hardly arise.
In the aforementioned method for inhibiting formation of hydrogen chloride (Inventions 11 & 12), it is preferable that the chloride ion concentration or pH of condensed water (for example overhead receiver water) in the main
distillation unit be measured, and the (β- hydroxyethyl) trimethylammonium hydroxide content be controlled based on the measurement results (Invention 13) . It is easy to measure the chloride ion concentration or pH of condensed water in the main distillation unit, and by using such measurement results it is possible to control a suitable choline content even when there are fluctuations in the salt content of the desalted crude oil. In the aforementioned method for inhibiting formation of hydrogen chloride (Inventions 11-13) , it is preferable
that the (β-hydroxyethyl) trimethylammonium hydroxide content be controlled such that the chloride ion concentration (sodium chloride conversion) of the overhead receiver water is 0-30 mg/L or the pH of the overhead receiver water is 5.5-7.0 (Invention 14).
BRIEF DESCRIPTION OF THE DRAWINGS
Figure 1 is a schematic diagram of one example of a boiler;
Figure 2 is a process drawing of one example of a crude oil atmospheric distillation method (2-columns type) ; and
Figure 3 shows a chart of the GC/MS measurement results for thermal decomposition of choline chloride.
DESCRIPTION OF THE PREFERRED EMBODIMENTS
Embodiments of the present invention are explained below. [Metal corrosion inhibitor] The metal corrosion inhibitor of the present invention contains the quaternary ammonium compound (quaternary ammonium compound A) described by general formula [1] below:
Figure imgf000018_0001
(wherein R1, R2 and R3 are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10.)
Examples of the hydrocarbon radicals with 1 to 4 carbon atoms in general formula [1] include methyl, ethyl, n-propyl, isopropyl, n-butyl, isobutyl, sec-butyl, t-butyl and other straight-chain or branched-chain alkyl radicals . Examples of quaternary ammonium compound A include hydroxymethyltrimethylammonium hydroxide, hydroxymethyltriethylammonium hydroxide, (2- hydroxyethyl) triethylammonium hydroxide and (3- hydroxypropyl ) trimethylammonium hydroxide .
In general formula [1] it is preferable that R1, R2 and R3 be the same or different hydrocarbon radicals with 1-3 carbon atoms, and that n be an integer between 1 and 4. With such a low molecular weight, quaternary ammonium compound A is highly soluble in water, enhancing the effect of the present invention in preventing corrosion even when
small quantities are added, (β- hydroxyethyl) trimethylammonium hydroxide (choline), which has methyl radicals for R1, R2 and R3 and an n of 2, is particularly preferable as quaternary ammonium compound A.
The metal corrosion inhibitor of the present invention can be composed entirely of quaternary ammonium compound A, but may also contain ammonia, neutralizing amines and other corrosion inhibitors, hydrazine, sodium sulfite, sugars and other oxygen scavengers and the like in addition of quaternary ammonium compound A.
There are no particular limits on the content of quaternary ammonium compound A in the metal corrosion inhibitor of the present invention so long as the effect of the present invention is achieved to prevent corrosion even when small quantities are added. A content of 1-100% by mass is normal, and 5-50% by mass is preferable.
Examples of unit metals of which corrosion is to be prevented by, the metal corrosion inhibitor of the present invention include for example iron, iron alloys, copper, copper alloys, aluminized steel and the like, but the present invention is not limited by these. The metal corrosion inhibitor of the present invention can prevent corrosion of unit metals in steam generating units and petroleum refining and petrochemical process by methods such as those described below.
[Method of inhibiting corrosion in a steam generating unit]
In the present invention, corrosion in a steam generating unit is inhibited through the use of quaternary ammonium compound A or the metal corrosion inhibitor of the present invention described above. The steam generating unit which is to be protected from corrosion is a unit which is capable of generating steam, such as a general boiler, the waste heat boiler of a petrochemical plant, gas turbine facility or the like, or the steam generator of a pressurized water reactor or the like, and which is liable to corrosion of the metal of the unit. The boiler may be a cylindrical boiler, water tube boiler, once-through boiler, cast-iron boiler or special boiler (indirect heating boiler, waste heat boiler, special fuel boiler, special fluid boiler or the like) .
The metal corrosion inhibitor or quaternary ammonium compound A of the present invention is added to water which may contact the inside of the steam generating unit, and undergoes a neutralizing reaction with acids in the water. For example, as shown in Figure 1, if the steam generating unit is a boiler there are three water systems (the feed water system, the inside of the boiler and the vapor/condensed water system) , and the metal corrosion inhibitor or quaternary ammonium compound A of the present invention can be added to any one or more than one of these water systems. However, because neutralization is more widespread if the metal corrosion inhibitor or quaternary ammonium compound A of the present invention is added further upstream, it is generally preferable to add it to the feed water system.
The method for adding the metal corrosion inhibitor or quaternary ammonium compound A of the present invention to the water system (injection method) may be continuous injection or intermittent injection. In the case of continuous injection, either quantified injection or flow rate proportional injection may be used, while in the case of intermittent injection, either suction injection or forcing injection may be used.
The quantity of the metal corrosion inhibitor or quaternary ammonium compound A of the present invention added to the water system will differ depending on pressures of boiler, processing methods and the like and cannot be decided definitely, but should be in the range of 0.1-50 mg/L or more preferably 0.2-10 mg/L with respect to the feed water. Practically, it can be controlled as necessary to meet required standards of water quality: for example, the pH of boiler water with a maximum use pressure of 10.0 MPa and with a volatile treatment should be controlled to 8.5- 9.5, in which case the quantity of the metal corrosion inhibitor or quaternary ammonium compound A of the present invention added should be 0.4-4 mg/L with respect to the feed water.
Because quaternary ammonium compound A has a high degree of dissociation and is strongly neutralizing in comparison with the ammonia and neutralizing amines used as conventional pH controllers, and it is also likely to remain in the boiler due to its relatively low volatility, it can efficiently prevent corrosion even when added in small quantities. Consequently, by adding the metal corrosion inhibitor or quaternary ammonium compound A of the present invention to a water system, especially to a feed water system, it is possible to efficiently neutralize and prevent corrosion in the feed water, the boiler and the vapor/condensed water system.
In particular, in boilers in which non-volatile alkalis such as caustic soda cannot be used or can only be used in limited quantities for structural or process reasons (for example the waste heat boilers of petrochemical plants), amines have conventionally been used in large quantities to control pH, but using the metal corrosion inhibitor or quaternary ammonium compound A of the present invention as a pH controller in such steam generating units, adequate corrosion prevention can be achieved with the addition of only small quantities.
Moreover, because quaternary ammonium compound A is strongly basic, it can maintain a higher pH than conventional amine salts even when amine carbonates produced by neutralization become dissolved in water. That is, with the present invention it is possible to effectively prevent secondary corrosion caused by neutralized salts. [A method for preventing corrosion of metal in petroleum refining and petrochemical process units]
In the present invention, corrosion of metal in a petroleum refining process unit or petrochemical process unit is prevented through the use of the aforementioned metal corrosion inhibitor or quaternary ammonium compound A. of the present invention. In petrochemical process, corrosion of the metal of units is especially likely to occur in the BTX refining process, ethylene manufacturing process, styrene monomer manufacturing process and the like. Examples of units to be protected from corrosion including units liable to corrosion by acids, such as the atmospheric distillation column and fractionating column and their attached connecting pipes, condensers, heat exchangers, receiving tanks and other units .
The metal corrosion inhibitor or quaternary ammonium compound A of the present invention is contained in fluids (oil, water, other liquids or gases) which may contact the inside of the petroleum refining or petrochemical process unit, and undergoes a neutralizing reaction with acids in the fluid. For example, to protect a fractionating column (or atmospheric distillation column) from corrosion, it can be added either through the side reflux line or directly into the column, or else into the feed line of the column. When controlling pH within the overhead condenser of a column, it should be added to the ejection pipe at the top of the column.
The method for adding the metal corrosion inhibitor or quaternary ammonium compound A of the present invention to a fluid (injection methods) may be continuous injection or intermittent injection. In the case of continuous injection, either quantified injection or flow rate proportional injection may be used.
The quantity of the metal corrosion inhibitor or quaternary ammonium compound A of the present invention added to the fluid may be controlled appropriately such that the pH in the system is within a range which is unlikely to cause corrosion of metal of the unit. For example in the top line of a crude oil atmospheric distillation column, it should be controlled to achieve a pH of 5.5-6.5 within the system.
Because quaternary ammonium compound A is more strongly basic than ammonia and neutralizing amines as the conventional pH controllers, it can effectively prevent corrosion even when added in small quantities. Consequently, by adding the metal corrosion inhibitor or quaternary ammonium compound A of the present invention to fluid which may contact the inside of a petroleum refining or petrochemical process unit, it is possible to efficiently prevent corrosion of metals of the unit.
In the atmospheric distillation column which is the most important unit in petroleum refining and petrochemical process, especially in petroleum refining process, conventionally it has been necessary to use neutralizing amines to neutralize hydrogen chloride derived from crude oil elements in order to prevent corrosion of metals in this unit, but neutralization produces amine hydrochlorides. Such amine hydrochlorides are highly hygroscopic, and some dissolve as they absorb water within the system. Such an aqueous solution in which amine hydrochlorides are dissolving normally has a low pH, and may cause secondary corrosion within the system. In the case of the present invention, however, because quaternary ammonium compound A is extremely basic, hydrochlorides of quaternary ammonium compound A do not lower pH dramatically even when dissolved in water. That is, secondary corrosion can be restrained with quaternary ammonium compound A because it is less corrosive than hydrochlorides of the ammonia, alkanolamines, methoxypropylzmine and the like conventionally used as pH controllers. In particular, in systems such as atmospheric distillation columns and fractionating columns in which hydrochlorides produced by neutralization accumulate, greater corrosion prevention effects can be achieved with the present invention.
[Hydrogen chloride formation inhibitor]
The hydrogen chloride formation inhibitor for a crude oil atmospheric distillation unit of the present invention
comprises (β-hydroxyethyl) trimethylammonium hydroxide
(hereunder called "choline") . It is preferable to use this hydrogen chloride formation inhibitor in the form of an aqueous solution of choline. In this case, choline should be contained in the hydrogen chloride formation inhibitor in the amount of about 5-100% by mass or preferably about 20- 50% by mass . If used according to the methods described below, the hydrogen chloride formation inhibitor of the present invention can prevent formation of hydrogen chloride and protect a crude oil atmospheric distillation unit from corrosion. When using the hydrogen chloride formation inhibitor of the present invention, alkaline chemicals such as sodium hydroxide can also be used in combination. [Hydrogen chloride formation inhibiting method]
In the present invention, hydrogen chloride formation is inhibited and corrosion of unit metal is prevented in a crude oil atmospheric distillation unit through the use of choline or the aforementioned hydrogen chloride formation inhibitor (both referred to hereunder as "the hydrogen chloride formation inhibitor.")
The hydrogen chloride formation inhibitor is preferably contained in the desalted crude oil between the crude oil desaltor and main distillation column of the crude oil atmospheric distillation unit, and more specifically it is preferably added to the desalted crude oil at the outlet of the crude oil desaltor. The hydrogen chloride formation inhibitor is preferably added to the desalted crude oil being controlled such that the choline content of the hydrogen chloride formation inhibitor is 0.1-5 times or preferably 1-2 times by molar equivalent the salts content of magnesium chloride, calcium chloride and other salts in the desalted crude oil.
Continuous injection is the preferable method for adding the hydrogen chloride formation inhibitor (injection method), and in particular it is preferable to inject continuously while controlling the content of the hydrogen chloride formation inhibitor according to the salts content of the desalted crude oil. In this case, it is preferable to measure the chloride ion concentration or pH of the top line or overhead system of the main distillation column, and to measure the chloride ion concentration or pH of the overhead receiver water of the main distillation column in particular, and to appropriately control the quantity of hydrogen chloride formation inhibitor to be added based on the measurement results . The salts content of desalted crude oil fluctuates, but it is possible to appropriately control the quantity of hydrogen chloride formation inhibitor to be added by measuring the chloride ion concentration or pH of the top line of the main distillation column in the above way.
Specifically, it is preferable that the quantity of hydrogen chloride formation inhibitor to be added be controlled such that the chloride ion concentration (sodium chloride conversion) of the overhead receiver water is 0-30 mg/L or more preferably 0-10 mg/L, or the pH of the overhead receiver water is 5.5-7.0 or more preferably 5.5-6.5.
Because the choline in the hydrogen chloride formation inhibitor has a high degree of dissociation and is strongly basic, it reacts with salts such as magnesium chloride, calcium chloride and the like in the desalted crude oil to produce choline chlorides, as shown by the following chemical formula:
CaCl2 + 2 ( (H3C)3N+C2HOH-OH~)
— > Ca ( OH) 2 + 2 ( (H3C) 3N+C2H4θHCl )
MgCl2 + 2 ( (H3C ) 3N+C2H4OH-OH~ )
--> Mg(OH)2 + 2( (H3C)3N+C2H40HC1)
Consequently, by adding the hydrogen chloride formation inhibitor to desalted crude oil as described above, it is possible to prevent formation of the hydrogen chloride itself and corrosion of metal of the unit due to hydrogen chloride. Because the choline in the hydrogen chloride formation inhibitor does not contain any metals which might adversely affect catalyst in the heavy oil direct desulfurization unit or the like, deterioration of the catalyst will not result even if the hydrogen chloride formation inhibitor is added in excess.
The choline chlorides produced in this way will be decomposed by heating as shown in the following formula, but the main decomposition products will be methyl chloride and amines such as trimethylamine and N,N-dimethylaminoethanol, with almost no hydrogen chloride produced.
( (H3C)3N+C2H4OH-OH-) —> R3N~R2NH + CH3Clt
Moreover, while hydrochlorides of the alkanolamines normally used as neutralizers cause secondary corrosion because they are highly hygroscopic, and absorb water inside the system, dissolve and lower pH, choline chlorides are more fluid than hydrochlorides of alkanolamines, and have extremely low metal corrosiveness, so they do not cause problems such as corrosion of the unit metal or line blockage .
One embodiment of the method for inhibiting formation of hydrogen chloride of the present invention is explained here with reference to the process drawing of a crude oil atmospheric distillation method (2-columns type) shown in Figure 2.
Crude oil is supplied continuously to crude oil desaltor 1, where it is desalted and dehydrated and solid matter is removed. Desalted crude oil exiting crude oil desaltor 1 is feeded to pre-distillation column 3 through line 2, while the hydrogen chloride formation inhibitor is added to line 2 at the outlet of crude oil desaltor 1 and converts magnesium chloride and calcium chloride to choline chlorides. Desalted crude oil to which the hydrogen chloride formation inhibitor has been added is feeded to pre-distillation column 3 through line 2, and evaporated water and light oil from the pre-distillation column 3 are supplied to main distillation column 7 through line 4.
Residue from pre-distillation column 3 is feeded to furnace 6 through line 5, heated to a prescribed temperature, then feeded to main distillation column 7, where it is fractionated into its various fractions (naphtha and kerosene, heavy kerosene, light gas oil, heavy gas oil and residue) . At this point, the partial magnesium chloride and calcium chloride remaining is hydrolyzed and may produce hydrogen chloride, but the resulting hydrogen chloride is captured as choline' chloride by unreacted choline.
Naphtha and kerosene from the top of main distillation column 7 are condensed through line 8, and collected in naphtha/kerosene receiving tank 9 (an example of an overhead receiver) . Gases and liquids are separated in this naphtha/kerosene receiving tank 9, and the fuel gas or LPG as the gas fraction is removed through line 10, while the naphtha and kerosene as the liquid fraction are removed through line 11. The water (overhead receiver water) which accumulates at the bottom of naphtha/kerosene receiving tank 9 is drained through drain 12 of naphtha/kerosene receiving tank 9.
The chloride ion concentration or pH of the overhead receiver water drained from naphtha/kerosene receiving tank 9 is measured. Based on the measurement results, the quantity of hydrogen chloride formation inhibitor added to line 2 at the outlet of crude oil desaltor 1 is controlled appropriately. The measurement of chloride ion concentration or pH and the control of quantity of hydrogen chloride formation inhibitor to be added can be automated as a sequential system.
The crude oil atmospheric distillation method described above uses an example of a 2-columns type, but the present invention is not limited thereby, and formation of hydrogen chloride can also be prevented by methods similar to those described above with a crude oil atmospheric distillation method using a different example of a 2-columns type, or with a crude oil atmospheric distillation method using a 1- column type .
Examples
The present invention is explained in more detail below with reference to examples, but the scope of the present invention is not limited by these or any other examples. [Example 1] [Neutralizing capability]
The pH values of (β-hydroxyethyl) trimethylammonium hydroxide (choline), monoethanolamine, ammonia, cyclohexylamine and morpholine were measured using a pH meter (manufactured by Horiba, product name pH Meter F-21) , and the respective base dissociation constants (Kb value, 25 °C) were calculated. These base dissociation constants are an indicator of neutralizing capability, with a larger number indicating that the substance has a higher degree of dissociation and is more strongly basic. The results are shown in Table 1. [Table 1]
Figure imgf000033_0001
It is understood from Table 1 that since (β- hydroxyethyl) trimethylammonium hydroxide has a larger base O 2004/044266
dissociation constant than the ammonia and amines, it is more strongly basic.
Next, the quantity of added ammonia or amines necessary to achieve a pH of 10.0, 10.5 or 11.0 in the boiler water was measured. A test boiler with evaporation of 5L/h was used as the boiler, operating under conditions of temperature of 170 °C, pressure of 0.8 Mpa, feed water was pure water, concentration rate of 100, blow rate of 1% and steam recovery rate of 0%, and pH was controlled by volatile treatment.
The results are shown in Table 2. The values in Table 2 are expressed as ratios (mass ratios) with the value for
(β-hydroxyethyl) trimethylammonium hydroxide given as 1.
[Table 2]
Figure imgf000034_0001
O 2004/044266
It is understood from Table 2 that (β- hydroxyethyl) trimethylammonium hydroxide can neutralize the boiler water efficiently with smaller quantities than the ammonia and amines .
[Example 2]
[Corrosiveness of hydrochlorides]
The following corrosion test was performed to evaluate the corrosiveness of hydrochlorides of ammonia or amines
( (β-hydroxyethyl) trimethylammonium hydroxide, ammonia, monoethanolamine, 3-methoxypropylamine and dimethylethanolamine) .
In the corrosion test, the hydrochlorides of the aforementioned ammonia and amines were poured into glass beakers at concentrations of 50% by mass (hydrochloride :pure water = 1:1), and test pieces (50 X 15 X 1mm, sanded with #400 sandpaper, degreased with toluene) of carbon steel
(SPCC) were immersed in the beakers for 20 hours at 50 °C under argon deaeration (anoxic conditions) . The test pieces were derusted after testing, and corrosion speed
(mg/dm2/day) was calculated from the difference in mass before and after testing. The results are shown in Table 3. O 2004/044266
[Table 3 ]
Figure imgf000036_0001
It is understood from Table 3 that the hydrochloride of
(β-hydroxyethyl) trimethylammonium hydroxide has a much lower corrosion speed than the ammonia and other amines . [Test Example 1] [Distillation test]
Aqueous solutions containing magnesium chloride and basic material (choline, sodium hydroxide, monoethanolamine, dimethylethanolamine) at a mole ratio of 1:2 and an aqueous solution containing magnesium chloride alone without any basic material were prepared and used as test solutions 1-5. The compositions of the test solutions (TS) are shown in Table 4. [Table 4 ]
Figure imgf000037_0001
In the test solutions above, guaranteed anhydrous magnesium chloride was used as the magnesium chloride, and industrial 48% sodium hydroxide as the sodium hydroxide.
Using the distillation method of JIS K2275 (Method for testing water content of crude oil and petroleum products) , the test solutions above were added to gas oil (commercial fuel) in amounts of 5% by mass and distilled for 0.5 hours at 100 °C to maximum 200 °C, and the chloride ion concentration in the distillate was measured. The results are shown in Table 5. [Table 5]
Figure imgf000038_0001
It is understood from Table 5 that choline exhibits a hydrogen chloride formation inhibiting effect or hydrogen chloride neutralizing effect equivalent to or greater than that of sodium hydroxide with respect to formation of hydrogen chloride derived from magnesium chloride (with test solution 5 which contains no basic material as the blank) . On the other hand, neither monoethanolamine nor dimethylethanolamine exhibited any hydrogen chloride formation inhibiting effect or hydrogen chloride neutralizing effect. [Test Example 2]
[Base dissociation constant]
The pH values of choline, monoethanolamine- and dimethylethanolamine were measured using a pH meter (manufactured by Horiba, product name pH Meter F-21) , and the respective base dissociation constants (Kb value, 25 °C and 170°C) were calculated. These base dissociation constants are an indicator of neutralizing capability, with a larger number indicating that the substance has a higher degree of dissociation and is more strongly basic. The results are shown in Table 6.
[Table 6]
Figure imgf000039_0001
It is understood from Table 6 that choline has a greater base dissociation constant than alkanolamines generally used as neutralizers, and is more strongly basic, [Test Example 3] [Corrosiveness test] Aqueous solutions of choline chloride, monoethanolamine hydrochloride and dimethylethanolamine in an amount of 50% by mass were prepared and used as the test solutions. The test solutions were poured into glass beakers, and test pieces (50 X 15 X 1mm, sanded with #400 sandpaper, degreased with toluene) of mild steel were immersed in the beakers for 18 hours at 90 °C under nitrogen deaeration (anoxic conditions) . The test pieces were derusted after testing, and corrosion speed (mg/dm2/day) was calculated from the difference in mass before and after testing. The results are shown in Table 7.
[Table 7]
Figure imgf000040_0001
It is understood from Table 7 that choline chloride has a much lower corrosion speed than chlorides of alkanolamines generally used as neutralizers, and consequently its corrosiveness is extremely low. [Test Example 4] [Thermal decomposition of choline chloride]
Choline chloride was subjected to thermal decomposition GC/MS analysis. 5989A manufactured by Hewlett Packard was used as the GC/MS analyzer, and DB624 manufactured by J&W (0.32mm X 30m, membrane thickness of 1.8 μm) was used as the column. The temperature for thermal decomposition of choline chloride was 760°C. A chart of the analysis results is given in Figure 3.
As shown by the chart in Figure 3, choline chloride produces methyl chloride, trimethylamine and N,N- dimethylaminoethanol by thermal decomposition, but does not produce hydrogen chloride.
INDUSTRIAL APPLICABILITY
The metal corrosion inhibitor of the present invention can adequately prevent corrosion of metal in a steam generating unit or petroleum refining or petrochemical process unit even when added in small quantities, and can reduce the risk of secondary corrosion because the neutralized salts produced do not dramatically lower pH when dissolved in water.
Moreover, with the method for preventing corrosion of metal of the present invention, corrosion of metal in a steam generating unit or petroleum refining or petrochemical process unit can be adequately prevented when the quantity of chemical added is small, and the risk of secondary corrosion can be reduced because the resulting neutralized salts do not dramatically lower pH even when dissolved in water.
In other words, the metal corrosion inhibitor and method for preventing corrosion of metal of the present invention are useful for inhibiting metal corrosion in steam generating units and petroleum refining and petrochemical process units.
In addition, with the hydrogen chloride formation inhibitor and method for inhibiting formation of hydrogen chloride of the present invention it is possible in a crude oil atmospheric distillation unit to prevent corrosion of the metal of the unit due to hydrogen chloride by inhibiting the formation of the hydrogen chloride itself. Moreover, the hydrogen chloride formation inhibitor and method for inhibiting formation of hydrogen chloride of the present invention do not adversely affect the catalyst in the heavy oil direct desulfurization unit, and there is no risk of metal corrosion or line blockage from salts produced by the hydrogen chloride formation inhibitor or method for inhibiting formation of hydrogen chloride of the present invention.
In other words, the hydrogen chloride formation inhibitor and method for inhibiting formation of hydrogen chloride of the present invention are useful in preventing the formation of hydrogen chloride in crude oil atmospheric distillation units.

Claims

CLAIMS 1. A metal corrosion inhibitor for preventing corrosion of metal in a steam generating unit or petroleum refining or petrochemical process unit, comprising a quaternary ammonium compound described by general formula [1] below:
R1
R2— N—(CH2)n-OH OH' .. . fl]
R3
(wherein R1, R2 and R3 are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10.)
2. The metal corrosion inhibitor according to Claim 1, wherein R1, R2 and R3 in the general formula [1] are the same or different hydrocarbon radicals with 1-3 carbon atoms, and n is an integer between 1 and 4.
3. The metal corrosion inhibitor according to Claim 1, wherein the quaternary ammonium compound described by the
general formula [1] is (β-hydroxyethyl) trimethylammonium hydroxide.
4. The metal corrosion inhibitor according to any of Claims 1 to 3, comprising the quaternary ammonium compound described by the general formula [1] in an amount of 1% by mass or more.
5. A method for preventing corrosion of metal in a steam generating unit, wherein a quaternary ammonium compound described by general formula [1] below:
Figure imgf000045_0001
(wherein R1, R2 and R3 are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10) is contained in water which may contact the inside of the steam generating unit.
6. The method for preventing corrosion of metal in a steam generating unit according to Claim 5, wherein the quaternary ammonium compound described by the general formula [1] is added in the range of 0.1-50 mg/L to feed water which may contact the inside of the steam generating unit.
7. A method for preventing corrosion of metal in a petroleum refining or petrochemical process unit, wherein a quaternary ammonium compound described by general formula [1] below:
Figure imgf000045_0002
(wherein R1, R and R3 are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10) is contained in fluid which may contact the inside of the petroleum refining or petrochemical process unit.
8. A method for preventing corrosion of metal in an atmospheric distillation column for petroleum refining process, wherein a quaternary ammonium compound described by general formula [1] below:
Figure imgf000046_0001
(in which R1, R2 and R3 are the same or different hydrocarbon radicals with 1 to 4 carbon atoms, and n is an integer between 1 and 10) is contained in fluid which may contact the inside of the atmospheric distillation column for petroleum refining process such that a pH value thereof at the top line of the atmospheric distillation column is 5.5- 6.5.
9. A hydrogen chloride formation inhibitor for a crude oil
atmospheric distillation unit, comprising (β- hydroxyethyl) trimethylammonium hydroxide.
10. The hydrogen chloride formation inhibitor for a crude oil atmospheric distillation unit according to Claim 9,
comprising (β-hydroxyethyl) trimethylammonium hydroxide in an amount of 5% by mass or more.
11. A method for inhibiting formation of hydrogen chloride
in a crude oil atmospheric distillation unit, wherein (β- hydroxyethyl) trimethylammonium hydroxide is contained in the desalted crude oil in between the crude oil desaltor and the main distillation column in the crude oil atmospheric distillation unit.
12. The method for inhibiting formation of hydrogen chloride in a crude oil atmospheric distillation unit
according to Claim 11, wherein the (β- hydroxyethyl) trimethylammonium hydroxide content is controlled to 0.1-5 times by molar equivalent the salts content in the desalted crude oil .
13. The method for inhibiting formation of hydrogen chloride in a crude oil atmospheric distillation unit according to Claim 11 or 12, wherein the chloride ion concentration or pH of the condensed water in the main
distillation unit is measured, and the (β- hydroxyethyl) trimethylammonium hydroxide content is controlled based on the measurement results.
14. The method for inhibiting formation of hydrogen chloride in a crude oil atmospheric distillation unit
according to any of Claims 11-13, wherein the (β- hydroxyethyl) trimethylammonium hydroxide content is controlled such that the chloride ion concentration (sodium chloride conversion) of the overhead receiver water is 0-30 mg/L or the pH of the overhead receiver water is 5.5-7.0.
PCT/JP2003/014392 2002-11-12 2003-11-12 Metal corrosion inhibitor and hydrogen chloride formation inhibitor in a crude oil atmospheric distillation unit WO2004044266A1 (en)

Priority Applications (3)

Application Number Priority Date Filing Date Title
EP03772720A EP1579033B1 (en) 2002-11-12 2003-11-12 Method for preventing corrosion of metals in steam generating units, petroleum and crude oil atmospheric distillation units
US10/533,910 US8177962B2 (en) 2002-11-12 2003-11-12 Metal corrosion inhibitor and hydrogen chloride formation inhibitor in a crude oil atmospheric distillation unit
AU2003279571A AU2003279571A1 (en) 2002-11-12 2003-11-12 Metal corrosion inhibitor and hydrogen chloride formation inhibitor in a crude oil atmospheric distillation unit

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
JP2002328857 2002-11-12
JP2002-328857 2002-11-12
JP2003-018630 2003-01-28
JP2003018630A JP3962919B2 (en) 2002-11-12 2003-01-28 Metal anticorrosive, metal anticorrosion method, hydrogen chloride generation inhibitor and method for preventing hydrogen chloride generation in crude oil atmospheric distillation equipment

Publications (1)

Publication Number Publication Date
WO2004044266A1 true WO2004044266A1 (en) 2004-05-27

Family

ID=32314081

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/JP2003/014392 WO2004044266A1 (en) 2002-11-12 2003-11-12 Metal corrosion inhibitor and hydrogen chloride formation inhibitor in a crude oil atmospheric distillation unit

Country Status (7)

Country Link
US (1) US8177962B2 (en)
EP (1) EP1579033B1 (en)
JP (1) JP3962919B2 (en)
KR (1) KR100679119B1 (en)
AU (1) AU2003279571A1 (en)
MY (1) MY143267A (en)
WO (1) WO2004044266A1 (en)

Cited By (24)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2008006855A2 (en) * 2006-07-11 2008-01-17 Taminco Inhibition of corrosion in cooling water system
CN100398175C (en) * 2006-04-11 2008-07-02 西安石油大学 Dew point controlled corrosion proof device for ordinary decompression column top system
WO2010062728A1 (en) * 2008-11-03 2010-06-03 Nalco Company Method of reducing corrosion in a crude unit
EP2348142A1 (en) * 2010-01-25 2011-07-27 Dominion Engineering, Inc. Method and composition for removing scale deposits formed on a metal surface within a steam generating system
WO2013142691A1 (en) * 2012-03-21 2013-09-26 Chemtreat, Inc. Preventing equipment fouling via corrosion reduction
WO2014018702A1 (en) 2012-07-25 2014-01-30 Nalco Company Design development and implementation of analyzer based control system and algorithm
WO2014055900A1 (en) 2012-10-05 2014-04-10 Ecolab Usa Inc. Stable percarboxylic acid compositions and uses thereof
US8728246B2 (en) 2010-01-26 2014-05-20 Westinghouse Electric Company, Llc Method and composition for removing deposits
WO2015126669A1 (en) * 2014-02-21 2015-08-27 Ecolab Usa Inc. Use of neutralizing agent in olefin or styrene production
US9242879B2 (en) 2012-03-30 2016-01-26 Ecolab Usa Inc. Use of peracetic acid/hydrogen peroxide and peroxide-reducing agents for treatment of drilling fluids, frac fluids, flowback water and disposal water
US9253978B2 (en) 2008-03-28 2016-02-09 Ecolab USA, Inc. Sulfoperoxycarboxylic acids, their preparation and methods of use as bleaching and antimicrobial agents
US9290448B2 (en) 2008-03-28 2016-03-22 Ecolab USA, Inc. Sulfoperoxycarboxylic acids, their preparation and methods of use as bleaching and antimicrobial agents
US9288992B2 (en) 2013-03-05 2016-03-22 Ecolab USA, Inc. Efficient stabilizer in controlling self accelerated decomposition temperature of peroxycarboxylic acid compositions with mineral acids
WO2016100694A1 (en) 2014-12-18 2016-06-23 Ecolab Usa Inc. Generation of peroxyformic acid through polyhydric alcohol formate
US9458388B2 (en) 2008-11-03 2016-10-04 Nalco Company Development and implementation of analyzer based on control system and algorithm
US9540598B2 (en) 2008-03-28 2017-01-10 Ecolab Usa Inc. Detergents capable of cleaning, bleaching, sanitizing and/or disinfecting textiles including sulfoperoxycarboxylic acids
US9585397B2 (en) 2013-03-05 2017-03-07 Ecolab Usa Inc. Peroxycarboxylic acid compositions suitable for inline optical or conductivity monitoring
WO2017040920A1 (en) 2015-09-04 2017-03-09 Ecolab Usa Inc. Performic acid on-site generator and formulator
EP3246380A1 (en) * 2016-05-18 2017-11-22 Bharat Petroleum Corporation Ltd. Crude unit overhead corrosion control using multi amine blends
US10165774B2 (en) 2013-03-05 2019-01-01 Ecolab Usa Inc. Defoamer useful in a peracid composition with anionic surfactants
EP3904489A4 (en) * 2018-12-27 2022-09-07 Kurita Water Industries Ltd. Method for eliminating pressure difference in distillation column
US11492277B2 (en) 2015-07-29 2022-11-08 Ecolab Usa Inc. Heavy amine neutralizing agents for olefin or styrene production
EP4136973A1 (en) 2012-10-05 2023-02-22 Ecolab USA Inc. Use of percarboxylic acid compositions
US12058999B2 (en) 2018-08-22 2024-08-13 Ecolab Usa Inc. Hydrogen peroxide and peracid stabilization with molecules based on a pyridine carboxylic acid

Families Citing this family (22)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CA2606762C (en) * 2005-04-29 2014-10-14 Scf Technologies A/S Method and apparatus for converting organic material
JP4711902B2 (en) * 2006-03-03 2011-06-29 伯東株式会社 Boiler corrosion control method
JP5034487B2 (en) * 2006-12-22 2012-09-26 三浦工業株式会社 Method for inhibiting corrosion of boiler equipment
BRPI0908613A8 (en) * 2008-05-15 2017-10-31 Angus Chemical MIXTURE, FUEL MIXTURE AND METHOD FOR PROVIDING MICROBIAL RESISTANCE TO A BIODIESEL FUEL
JP5691134B2 (en) * 2009-03-31 2015-04-01 栗田工業株式会社 How to treat boilers that are not operating
US20100242490A1 (en) * 2009-03-31 2010-09-30 General Electric Company Additive delivery systems and methods
JP6215511B2 (en) * 2010-07-16 2017-10-18 栗田工業株式会社 Anticorrosive for boiler
RU2571413C2 (en) * 2011-06-10 2015-12-20 Бехтел Хайдрокарбон Текнолоджи Солюшнз, Инк. Device and methods for elemental sulphur removal from carbon fluid
WO2013130123A1 (en) * 2012-02-28 2013-09-06 General Electric Company Steam generator additives to miniminze fouling and corrosion in crude towers
US10006128B2 (en) 2012-09-28 2018-06-26 Ecolab Usa Inc. Quaternary and cationic ammonium surfactants as corrosion inhibitors
JP2016030853A (en) * 2014-07-29 2016-03-07 大阪瓦斯株式会社 Piping equipment chemical addition method and surface treatment agent
RU2735513C2 (en) * 2015-05-13 2020-11-03 Родиа Операсьон Corrosion inhibitor compositions
WO2017058693A1 (en) * 2015-09-29 2017-04-06 Dow Global Technologies Llc Method and composition for neutralizing acidic components in petroleum refining units
AU2016364837B2 (en) * 2015-12-04 2021-10-28 Bl Technologies, Inc. System and method of predictive analytics for control of an overhead crude section of a hydrocarbon refining process
JP6065138B1 (en) * 2016-03-22 2017-01-25 栗田工業株式会社 Method for reducing corrosive ions in aromatic compound extraction solvents
US10822547B2 (en) 2017-12-12 2020-11-03 Baker Hughes Holdings Llc Basic ionic liquids as hydrochloric acid scavengers in refinery crude processing
US11643384B2 (en) 2018-04-26 2023-05-09 Kurita Water Industries Ltd. Stabilization of compositions comprising quaternary trialkylalkanolamine hydroxide
JP6933238B2 (en) * 2018-12-27 2021-09-08 栗田工業株式会社 How to eliminate the differential pressure in the distillation column
US12096768B2 (en) 2019-08-07 2024-09-24 Ecolab Usa Inc. Polymeric and solid-supported chelators for stabilization of peracid-containing compositions
JP6939872B2 (en) * 2019-12-13 2021-09-22 栗田工業株式会社 Distillation column management system, distillation column state analysis method and distillation column management method
BR112022015069A2 (en) * 2020-01-30 2022-09-20 Kurita Water Ind Ltd METHOD OF REDUCTION OR PREVENTION OF CORROSION OR FOLLOWING IN AN APPLIANCE AND USE OF A COMPOUND
US20240183038A1 (en) * 2022-11-22 2024-06-06 Saudi Arabian Oil Company Ethoxylated fatty diamine as a corrosion inhibitor for pipelines and storage tanks

Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JPH03291390A (en) * 1990-04-06 1991-12-20 Hakutou Kagaku Kk Corrosion inhibitor preventing heaping and blocking
JP2002129366A (en) * 2000-10-23 2002-05-09 Kurita Water Ind Ltd Corrosion prevention method for non-operating boiler

Family Cites Families (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2402793A (en) * 1944-02-28 1946-06-25 Standard Oil Co Aqueous rust preventive composition
JPS60243186A (en) * 1984-05-18 1985-12-03 Nippon Shokubai Kagaku Kogyo Co Ltd Anti-freeze
US4600518A (en) 1985-07-15 1986-07-15 Nalco Chemical Company Choline for neutralizing naphthenic acid in fuel and lubricating oils
JPS62281332A (en) * 1986-05-29 1987-12-07 Fujitsu Ltd Etching method
JPH02209493A (en) * 1989-02-09 1990-08-20 Kurita Water Ind Ltd Anticorrosive for steam or condensate system
JP2906590B2 (en) * 1990-06-14 1999-06-21 三菱瓦斯化学株式会社 Surface treatment agent for aluminum wiring semiconductor substrate
US5302253A (en) * 1992-04-13 1994-04-12 Nalco Chemical Company On-line acid monitor and neutralizer feed control of the overhead water in oil refineries
US5965785A (en) * 1993-09-28 1999-10-12 Nalco/Exxon Energy Chemicals, L.P. Amine blend neutralizers for refinery process corrosion
US5635458A (en) 1995-03-01 1997-06-03 M-I Drilling Fluids, L.L.C. Water-based drilling fluids for reduction of water adsorption and hydration of argillaceous rocks
MY117988A (en) 1995-10-03 2004-08-30 Nor Ind Inc Cleaning compositions for oil and gas well, lines, casings, formations and equipment and methods of use
DE60110072T2 (en) 2001-09-27 2006-01-26 Kurita Europe Gmbh Process for preventing contamination and corrosion by ammonium chloride and ammonium sulfate

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JPH03291390A (en) * 1990-04-06 1991-12-20 Hakutou Kagaku Kk Corrosion inhibitor preventing heaping and blocking
JP2002129366A (en) * 2000-10-23 2002-05-09 Kurita Water Ind Ltd Corrosion prevention method for non-operating boiler

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See also references of EP1579033A4 *

Cited By (63)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN100398175C (en) * 2006-04-11 2008-07-02 西安石油大学 Dew point controlled corrosion proof device for ordinary decompression column top system
WO2008006855A2 (en) * 2006-07-11 2008-01-17 Taminco Inhibition of corrosion in cooling water system
WO2008006855A3 (en) * 2006-07-11 2008-05-29 Taminco Inhibition of corrosion in cooling water system
US9540598B2 (en) 2008-03-28 2017-01-10 Ecolab Usa Inc. Detergents capable of cleaning, bleaching, sanitizing and/or disinfecting textiles including sulfoperoxycarboxylic acids
US10017720B2 (en) 2008-03-28 2018-07-10 Ecolab Usa Inc. Sulfoperoxycarboxylic acids, their preparation and methods of use as bleaching and antimicrobial agents
US10077415B2 (en) 2008-03-28 2018-09-18 Ecolab Usa Inc. Detergents capable of cleaning, bleaching, sanitizing and/or disinfecting textiles including sulfoperoxycarboxylic acids
US9676711B2 (en) 2008-03-28 2017-06-13 Ecolab Usa Inc. Sulfoperoxycarboxylic acids, their preparation and methods of use as bleaching and antimicrobial agents
US9359295B2 (en) 2008-03-28 2016-06-07 Ecolab USA, Inc. Sulfoperoxycarboxylic acids, their preparation and methods of use as bleaching and antimicrobial agents
US11827867B2 (en) 2008-03-28 2023-11-28 Ecolab Usa Inc. Sulfoperoxycarboxylic acids, their preparation and methods of use as bleaching and antimicrobial agents
US10323218B2 (en) 2008-03-28 2019-06-18 Ecolab Usa Inc. Sulfoperoxycarboxylic acids, their preparation and methods of use as bleaching and antimicrobial agents
US10669512B2 (en) 2008-03-28 2020-06-02 Ecolab Usa Inc. Sulfoperoxycarboxylic acids, their preparation and methods of use as bleaching and antimicrobial agents
US9290448B2 (en) 2008-03-28 2016-03-22 Ecolab USA, Inc. Sulfoperoxycarboxylic acids, their preparation and methods of use as bleaching and antimicrobial agents
US11015151B2 (en) 2008-03-28 2021-05-25 Ecolab Usa Inc. Sulfoperoxycarboxylic acids, their preparation and methods of use as bleaching and antimicrobial agents
US9253978B2 (en) 2008-03-28 2016-02-09 Ecolab USA, Inc. Sulfoperoxycarboxylic acids, their preparation and methods of use as bleaching and antimicrobial agents
EP3744815A1 (en) * 2008-11-03 2020-12-02 Nalco Company Method of reducing corrosion and corrosion byproduct deposition in a crude unit
KR20110093862A (en) * 2008-11-03 2011-08-18 날코 컴퍼니 Method of reducing corrosion in a crude unit
WO2010062728A1 (en) * 2008-11-03 2010-06-03 Nalco Company Method of reducing corrosion in a crude unit
US9969947B2 (en) 2008-11-03 2018-05-15 Ecolab Usa Inc. Method of reducing corrosion and corrosion byproduct deposition in a crude unit
US9611431B2 (en) 2008-11-03 2017-04-04 Nalco Company Method of reducing corrosion and corrosion byproduct deposition in a crude unit
US11326113B2 (en) 2008-11-03 2022-05-10 Ecolab Usa Inc. Method of reducing corrosion and corrosion byproduct deposition in a crude unit
US9150793B2 (en) 2008-11-03 2015-10-06 Nalco Company Method of reducing corrosion and corrosion byproduct deposition in a crude unit
CN102203219A (en) * 2008-11-03 2011-09-28 纳尔科公司 Method of reducing corrosion in a crude unit
US10316261B2 (en) 2008-11-03 2019-06-11 Ecolab Usa Inc. Method of reducing corrosion and corrosion byproduct deposition in a crude unit
KR101674229B1 (en) 2008-11-03 2016-11-08 날코 컴퍼니 Method of reducing corrosion in a crude unit
US9458388B2 (en) 2008-11-03 2016-10-04 Nalco Company Development and implementation of analyzer based on control system and algorithm
EP2348142A1 (en) * 2010-01-25 2011-07-27 Dominion Engineering, Inc. Method and composition for removing scale deposits formed on a metal surface within a steam generating system
US8728246B2 (en) 2010-01-26 2014-05-20 Westinghouse Electric Company, Llc Method and composition for removing deposits
US9321664B2 (en) 2011-12-20 2016-04-26 Ecolab Usa Inc. Stable percarboxylic acid compositions and uses thereof
US9902627B2 (en) 2011-12-20 2018-02-27 Ecolab Usa Inc. Stable percarboxylic acid compositions and uses thereof
US9382629B2 (en) 2012-03-21 2016-07-05 Chemtreat, Inc. Preventing equipment fouling via corrosion reduction
WO2013142691A1 (en) * 2012-03-21 2013-09-26 Chemtreat, Inc. Preventing equipment fouling via corrosion reduction
US8951467B2 (en) 2012-03-21 2015-02-10 Chemtreat, Inc. Preventing equipment fouling via corrosion reduction
US9242879B2 (en) 2012-03-30 2016-01-26 Ecolab Usa Inc. Use of peracetic acid/hydrogen peroxide and peroxide-reducing agents for treatment of drilling fluids, frac fluids, flowback water and disposal water
US9926214B2 (en) 2012-03-30 2018-03-27 Ecolab Usa Inc. Use of peracetic acid/hydrogen peroxide and peroxide-reducing agents for treatment of drilling fluids, frac fluids, flowback water and disposal water
US10017403B2 (en) 2012-03-30 2018-07-10 Ecolab Usa Inc. Use of peracetic acid/hydrogen peroxide and peroxide-reducing enzymes for treatment of drilling fluids, frac fluids, flowback water and disposal water
US10023484B2 (en) 2012-03-30 2018-07-17 Ecolab Usa Inc. Use of peracetic acid/hydrogen peroxide and peroxide-reducing agents for treatment of drilling fluids, frac fluids, flowback water and disposal water
WO2014018702A1 (en) 2012-07-25 2014-01-30 Nalco Company Design development and implementation of analyzer based control system and algorithm
US9834732B2 (en) 2012-07-25 2017-12-05 Nalco Company Llc Development and implementation of analyzer based control system and algorithm
US10563142B2 (en) 2012-07-25 2020-02-18 Ecolab Usa Inc. Development and implementation of analyzer based control system and algorithm
EP3574758A1 (en) 2012-10-05 2019-12-04 Ecolab USA Inc. Stable percarboxlic acid compositions and uses thereof
US11939241B2 (en) 2012-10-05 2024-03-26 Ecolab Usa Inc. Stable percarboxylic acid compositions and uses thereof
EP4136973A1 (en) 2012-10-05 2023-02-22 Ecolab USA Inc. Use of percarboxylic acid compositions
WO2014055900A1 (en) 2012-10-05 2014-04-10 Ecolab Usa Inc. Stable percarboxylic acid compositions and uses thereof
US11180385B2 (en) 2012-10-05 2021-11-23 Ecolab USA, Inc. Stable percarboxylic acid compositions and uses thereof
EP2984929A1 (en) 2012-10-05 2016-02-17 Ecolab USA Inc. Stable percarboxylic acid compositions and uses thereof
US9288992B2 (en) 2013-03-05 2016-03-22 Ecolab USA, Inc. Efficient stabilizer in controlling self accelerated decomposition temperature of peroxycarboxylic acid compositions with mineral acids
US10031081B2 (en) 2013-03-05 2018-07-24 Ecolab Usa Inc. Peroxycarboxylic acid compositions suitable for inline optical or conductivity monitoring
US9675076B2 (en) 2013-03-05 2017-06-13 Ecolab Usa Inc. Peroxycarboxylic acid compositions suitable for inline optical or conductivity monitoring
US10165774B2 (en) 2013-03-05 2019-01-01 Ecolab Usa Inc. Defoamer useful in a peracid composition with anionic surfactants
US10893674B2 (en) 2013-03-05 2021-01-19 Ecolab Usa Inc. Efficient stabilizer in controlling self accelerated decomposition temperature of peroxycarboxylic acid compositions with mineral acids
US11026421B2 (en) 2013-03-05 2021-06-08 Ecolab Usa Inc. Efficient stabilizer in controlling self accelerated decomposition temperature of peroxycarboxylic acid compositions with mineral acids
US9585397B2 (en) 2013-03-05 2017-03-07 Ecolab Usa Inc. Peroxycarboxylic acid compositions suitable for inline optical or conductivity monitoring
US11206826B2 (en) 2013-03-05 2021-12-28 Ecolab Usa Inc. Defoamer useful in a peracid composition with anionic surfactants
US9297081B2 (en) 2014-02-21 2016-03-29 Ecolab Usa Inc. Use of neutralizing agent in olefin or styrene production
WO2015126669A1 (en) * 2014-02-21 2015-08-27 Ecolab Usa Inc. Use of neutralizing agent in olefin or styrene production
EP3766523A1 (en) 2014-12-18 2021-01-20 Ecolab USA Inc. Generation of peroxyformic acid through polyhydric alcohol formate
WO2016100694A1 (en) 2014-12-18 2016-06-23 Ecolab Usa Inc. Generation of peroxyformic acid through polyhydric alcohol formate
US11492277B2 (en) 2015-07-29 2022-11-08 Ecolab Usa Inc. Heavy amine neutralizing agents for olefin or styrene production
WO2017040920A1 (en) 2015-09-04 2017-03-09 Ecolab Usa Inc. Performic acid on-site generator and formulator
EP4148043A1 (en) 2015-09-04 2023-03-15 Ecolab USA Inc. A method of sanitizing and/or disinfecting a surface using an on-site generated performic acid composition.
EP3246380A1 (en) * 2016-05-18 2017-11-22 Bharat Petroleum Corporation Ltd. Crude unit overhead corrosion control using multi amine blends
US12058999B2 (en) 2018-08-22 2024-08-13 Ecolab Usa Inc. Hydrogen peroxide and peracid stabilization with molecules based on a pyridine carboxylic acid
EP3904489A4 (en) * 2018-12-27 2022-09-07 Kurita Water Industries Ltd. Method for eliminating pressure difference in distillation column

Also Published As

Publication number Publication date
KR20050086495A (en) 2005-08-30
MY143267A (en) 2011-04-15
US8177962B2 (en) 2012-05-15
KR100679119B1 (en) 2007-02-06
JP3962919B2 (en) 2007-08-22
US20060043340A1 (en) 2006-03-02
AU2003279571A1 (en) 2004-06-03
JP2004211195A (en) 2004-07-29
EP1579033A1 (en) 2005-09-28
EP1579033B1 (en) 2013-01-30
EP1579033A4 (en) 2007-11-21

Similar Documents

Publication Publication Date Title
US8177962B2 (en) Metal corrosion inhibitor and hydrogen chloride formation inhibitor in a crude oil atmospheric distillation unit
US4842716A (en) Ethylene furnace antifoulants
EP2820110B1 (en) Steam generator additives to minimize fouling and corrosion in crude towers
EP1298185B1 (en) Method for preventing fouling and corrosion caused by ammonium chloride and ammonium sulphates
US20170051194A1 (en) Fluoro-inorganics for acidification or neutralization of water systems
CN102953064B (en) Mannich base corrosion-inhibiting neutralizer and preparation method thereof
US4595723A (en) Corrosion inhibitors for alkanolamines
US10253274B2 (en) Compounds and methods for inhibiting corrosion in hydrocarbon processing units
US4596849A (en) Corrosion inhibitors for alkanolamines
CA1314704C (en) Method of inhibiting corrosion of metal surfaces in contact with a corrosive hydrocarbon containing medium
JP3692449B2 (en) Hydrogen chloride generation inhibitor and hydrogen chloride generation prevention method in crude oil atmospheric distillation equipment
CN100523301C (en) Metal corrosion inhibitor and hydrogen chloride formation inhibitor in a crude oil atmospheric distillation unit
EP0002634B1 (en) Composition and method for inhibiting corrosion in steam condensate systems
US20220364242A1 (en) Method for Reducing or Preventing Corrosion or Fouling Caused by Acidic Compounds
EP0600606B1 (en) Neutralizing amines with low salt precipitation potential
US20190119580A1 (en) Process for controlling corrosion in petroleum refining units
CN102953065B (en) Corrosion inhibition neutralizer for metal corrosion prevention and preparation method thereof
Kolmetz et al. Improve the Reliability of High Flux Reboilers A Treatment Approach for Dilution Steam Generator (DSG) Reboilers in Ethylene Plants
Robinson et al. An integrated approach to optimizing corrosion control for refinery process and boiler systems
Raman Temperature effects on inhibitors and corrosion inhibition
CN114921789A (en) Neutralization corrosion inhibitor
Lee Coal fired power plant water chemistry issues: Amine selection at supercritical conditions and sodium leaching from ion exchange mixed beds

Legal Events

Date Code Title Description
AK Designated states

Kind code of ref document: A1

Designated state(s): AE AG AL AM AT AU AZ BA BB BG BR BY BZ CA CH CN CO CR CU CZ DE DK DM DZ EC EE EG ES FI GB GD GE GH GM HR HU ID IL IN IS KE KG KP KR KZ LC LK LR LS LT LU LV MA MD MG MK MN MW MX MZ NI NO NZ OM PG PH PL PT RO RU SC SD SE SG SK SL SY TJ TM TN TR TT TZ UA UG US UZ VC VN YU ZA ZM ZW

AL Designated countries for regional patents

Kind code of ref document: A1

Designated state(s): BW GH GM KE LS MW MZ SD SL SZ TZ UG ZM ZW AM AZ BY KG KZ MD RU TJ TM AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IT LU MC NL PT RO SE SI SK TR BF BJ CF CG CI CM GA GN GQ GW ML MR NE SN TD TG

121 Ep: the epo has been informed by wipo that ep was designated in this application
ENP Entry into the national phase

Ref document number: 2006043340

Country of ref document: US

Kind code of ref document: A1

WWE Wipo information: entry into national phase

Ref document number: 10533910

Country of ref document: US

WWE Wipo information: entry into national phase

Ref document number: 1020057008334

Country of ref document: KR

WWE Wipo information: entry into national phase

Ref document number: 2003772720

Country of ref document: EP

WWE Wipo information: entry into national phase

Ref document number: 20038A56964

Country of ref document: CN

WWP Wipo information: published in national office

Ref document number: 1020057008334

Country of ref document: KR

WWP Wipo information: published in national office

Ref document number: 2003772720

Country of ref document: EP

WWP Wipo information: published in national office

Ref document number: 10533910

Country of ref document: US