• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    synergistic method for increased h2s / mercaptan removal. the present invention relates to the use of a dialdehyde (for example, glyoxal) and a nitrogen-containing removal agent (for example, a triazine) when injected separately into the medium containing hydrogen sulfide (h2s) and / or mercaptans for removing h2s and / or mercaptans from this gives a synergistically better reaction rate and total removal efficiency, that is, capacity, over the use of the dialdehyde, or the nitrogen-containing removal agent used alone, but in the same total amount of the dialdehyde and agent nitrogen-containing removal the medium can include an aqueous phase, a gas phase, a hydrocarbon phase and mixtures of a gas and / or hydrocarbon phase with an aqueous phase.
    公开号:BR102012016101B1
    申请号:R102012016101-0
    申请日:2012-06-28
    公开日:2020-09-15
    发明作者:Carlos M. Menendez；Vladimir Jovancicevic；Sunder Ramachandran
    申请人:Baker Hugues Incorporated；
    IPC主号:
    专利说明:

    TECHNICAL FIELD
    [0001] The present invention relates to methods and compositions for removing H2S and / or mercaptans from fluids, and, more particularly, relates, in a non-limiting embodiment, to methods and compositions for removing H2S and / or mercaptans from fluids using a dialdehyde and a nitrogen-containing removal agent. TECHNICAL BACKGROUND
    [0002] In drilling, borehole completion, production, transportation, storage and processing of crude oil and natural gas, including waste water associated with crude oil and gas production, and in the storage of residual fuel oil, H2S and / or mercaptans are often found. The presence of H2S and mercaptans is unpleasant because they often react with other hydrocarbons or fuel system components. Another reason that H2S and mercaptans are unpleasant is that they are often highly corrosive. Yet another reason that H2S and mercaptans are undesirable is that they often have highly harmful odors. The odors resulting from H2S and mercaptans are detectable by the human nose in comparatively low concentrations, and are well known. For example, mercaptans are used to odor natural gas, and are used as a repellent by smelly weasels, and other animals.
    [0003] The predominant H2S and mercaptan removal agents for natural gas and crude oil are monoethanolamine (MEA) and monomethylamine (MMA) triazines. The use of triazines for H2S and mercaptan removal agents is described in United States Patent Nos. 5,347,004; 5,554,349; 5,958,352; and 6,663,841 assigned to Baker Hughes Incorporated.
    [0004] Glyoxal dialdehyde (C2H2O2) and acrolein aldehyde (C3H4O) were used as H2S removal agents in these examples. Glyoxal can be corrosive to smooth steel under some conditions. Acrolein is an extremely toxic substance that operators do not like to use.
    [0005] It would be desirable if new H2S and / or mercaptan removal agents, or new synergistic combinations of old H2S and mercaptan removal agents could be contacted that are very effective, but that overcome the deficiencies of previous removal agents. SUMMARY
    [0006] A non-restrictive version of a method for removing hydrogen sulfide and / or mercaptans from the medium is provided which includes, but is not necessarily limited to, an aqueous phase, a gas phase, a hydrocarbon phase and mixtures of a gas and / or hydrocarbon phase with an aqueous phase, the medium of which also comprises hydrogen sulfide and / or mercaptans. The method involves contacting the medium separately with an amount effective to synergistically remove hydrogen sulfide and / or mercaptans from at least one dialdehyde, and an amount effective to synergistically remove hydrogen sulfide and / or mercaptans from at least one nitrogen-containing removal agent. . The at least one dialdehyde and at least one nitrogen-containing removal agent are not mixed together before each contact separately with the medium. The amount of hydrogen sulfide and / or mercaptans removed is greater as compared to a method of contacting the medium with at least one dialdehyde alone and a method of contacting the medium with at least one nitrogen-containing removal agent alone, where they are separately used in equal total amounts depending on the combined effective amount of the dialdehyde and the nitrogen-containing removal agent. BRIEF DESCRIPTION OF THE DRAWINGS
    [0007] Figure 1 is a schematic diagram of a specially designed valve equipped with two separate injection lines for injecting a dialdehyde and a nitrogen-containing removal agent separately into a flow producing fluid;
    [0008] Figure 2 is a graph showing the difference between the concentration of H2S gas sprayed through a brine solution and the existing H2S concentration of gas over time after a fixed amount of glyoxal and triazine is separately co-jetted as compared to when glyoxal and triazine are each injected alone, but in equivalent amounts; and
    [0009] Figure 3 is a graph showing the difference between the concentration of H2S gas sprayed through a brine solution and the existing H2S concentration of gas over time after a fixed amount of glyoxal and triazine is separately co-jetted as compared to when glyoxal and triazine are mixed together and injected, but in equivalent amounts.
    [0010] It will be understood that Figure 1 is not necessarily shown in scale or proportion, and that certain characteristics may be exaggerated for clarity, and that any simplifications or exaggerations do not limit the methods described here. DETAILED DESCRIPTION
    [0011] It has surprisingly been found that a synergistic in-situ combination of glyoxal and triazine-based hydrogen sulfide removal agents can remove H2S present in wet natural gas, oil and aqueous solutions, such as brine. The method involves removing H2S in natural gas, oil, aqueous solutions and combinations of these by a synergistic combination of a dialdehyde, such as glyoxal, and a conventional nitrogen-containing removal agent, such as a triazine, by injecting them separately into the streams. gas, gas / water, oil and oil / water. The mixing of the components, if any, occurs in the stream. The resulting removal agent mixture formed in situ significantly increases the reaction rate and total cleaning efficiency, as compared to the use of either the dialdehyde, or the nitrogen-containing removal agent, separately, but in the same proportions. It has surprisingly been found that if the dialdehyde and the nitrogen-containing removal agent are injected together, particularly when they are glyoxal and a triazine, that a reaction product is formed that does not operate to effectively clean H2S, in a non-limiting embodiment.
    [0012] More particularly, the method involves the effective removal of H2S and / or mercaptans (collectively known as sulfur-containing compounds) from various media including, but not necessarily limited to, hydrocarbon phase (e.g., oil and natural gas) and water phases (for example, brines) and mixtures thereof, by introducing a combination of a dialdehyde and a nitrogen-removing agent into the fluid, but by co-injection without contacting each other before being diluted in the fluid to form a synergistic mixture, while greatly preventing the formation of a reaction product between the two. It will be understood that a small portion of a reaction product can form within the fluid, but in many cases, too much reaction product is not expected to be formed, which will adversely affect the removal method.
    [0013] In addition to glyoxal, other dialdehydes expected to be useful in the method described herein include, but are not necessarily limited to, malondialdehyde, succindialdehyde, glutaraldehyde, phthalialdehyde, and the like, and combinations thereof.
    [0014] Suitable nitrogen-containing removal agents include, but are not necessarily limited to, triazines (eg, hexahydrotriazines produced by reacting formaldehyde with an alkanolamine, such as monoethanolamine (MEA), and other triazines produced using a alkylamine, such as monomethylamine, and an alkoxyalkylamine, such as 3-methoxypropylamine (MOPA), etc.); where other suitable nitrogen-containing removal agents include monomethylamine (MMA); monoethylamine; dimethylamine; dipropylamine; trimethylamine; triethylamine; tripropylamine; monomethanolamine; dimethanolamine; trimethanolamine; diethanolamine (DEA); triethanolamine (TEA); monoisopropanolamine; dipropanolamine; diisopropanolamine; tripropanolamine; N-methylethylamine; dimethyl ethanol amine; methyl diethanolamine; dimethyl amino ethanol; diamines, such as those of United States Patent No. 5,074,991; imines; imidazolines; hydroxy amino alkyl ethers; morpholines; pyrrolidones; piperidones; alkylpyridines; aminomethylcyclopentylamine; 1-2-cyclohexanediamine; 1,5-pentanediamine; 1,6-hexanediamine; 1H-azepine, hexahydro; 1,4-butanediamine; alkylene polyamine / formaldehyde reaction products; bis- (tertiarybutylminoethoxy) -ethane (BTEE); ethoxyethoxyethanol tertiaryributylamine (EEETB); polyvalent metal chelates of aminocarboxylic acids; quaternary ammonium salts; polyethylonimine; polyalylamine; polyvinylamine; aminocarbinols; amines; bisoxazolidines; reaction products of ethylene diamine with formaldehyde such as those of United States Patent No. 5,314,672; reaction product of N-butylamine formaldehyde, and combinations thereof. In another non-limiting embodiment, monoethanolamine (M EA) is absent.
    [0015] The weight ratio of dialdehyde to nitrogen-containing removal agent can vary from about 5/95, independently, to about 95/5, where the dialdehyde is in a 40% by weight aqueous solution, alternatively about from 25/75, independently, to about 75/25, and, alternatively, from about 40/60, independently, to about 60/40. The term "independently" when used in conjunction with a range here, means that any lower limit can be combined with any upper limit to give a valid alternative range.
    [0016] In specific applications to remove H2S from crude oil or other fluid, the hydrogen sulfide / mercaptan removal agent, that is, a combined effective amount of dialdehyde and effective amount of nitrogen-containing removal agent, varying from about 1, independently, at about 100,000 ppm, can be introduced into the fluid, alternatively from about 100, independently, at about 10,000 ppm, alternatively from about 50, independently, at about 5,000 ppm.
    [0017] In an alternative embodiment, surfactants can optionally be used together with the dialdehyde, or together with the nitrogen-containing removal agent. Surfactants can help to disperse H2S / mercaptan removal agents in the fluid. Suitable non-nitrogen-containing surfactants include, but are not necessarily limited to, alkoxylated alkyl alcohols and salts thereof, and alkoxylated alkyl phenols and salts thereof, alkyl and aryl sulfonates, sulfates, phosphates, carboxylates, polyoxyalkyl glycols, fatty alcohols, polyoxyethylene glycol sorbitan alkyl esters, sorbitan alkyl esters, polysorbates, glycosides, and the like, and combinations thereof. Other suitable surfactants may include, but are not necessarily limited to, quaternary amine compounds, amine oxide surfactants, and the like.
    [0018] Suitable solvent compositions for H2S / mercaptan removal agent include, but are not necessarily limited to, water, formamide, propylene carbonate, tetrahydrofuran, alcohols, glycols, and mixtures of these alone, or without water. Suitable alcohols include methanol and ethanol. Ethylene glycol can also be used as a solvent during the winter months for anti-freeze purposes.
    [0019] The method can be achieved in a non-limiting embodiment using a valve 10 as shown in Figure 1, where the valve 10 intersects and is connected to a fluid flow duct 12, such as previously described production fluids. Valve 10 has a first injection line 14 with its first valve 16, and a second injection line 18 with its respective second valve 20. The first injection line 14 and the second injection line 18 are in the common injection line 22, which feeds the duct 12. Regardless of whether the dialdehyde or nitrogen-containing removal agent is the first component (injected via the first injection line 14), or the second component (injected via the second injection line 18), the components they are not mixed together before injection into the conduit fluid 12, for example, within the common injection line 22. Any mixture of a subsequent component with residual initial component in valve 10 can be considered negligible. Alternatively, or in addition to, the apparatus shown in Figure 1 and described above, may be an injection point or multiple injection points in conduit 12 for each of the dialdehyde and the nitrogen-containing removal agent.
    [0020] It is expected that these methods and compositions can be used to remove hydrogen sulfide present in natural gas produced from natural gas wells, including where the medium is a gas phase. They can also be used to remove hydrogen sulfide from crude oil. Additionally, they can be used to remove hydrogen sulfide from brines containing hydrogen sulfide. Consequently, these compositions and methods can be advantageously used in refineries, wastewater and produced water treatment plants, facilities that produce hydrogen, and other industrial processes.
    [0021] When the method clears H2S and / or mercaptans from a gas phase, the method can be practiced by contacting the gas phase with droplets of the two types of removal agents. With respect to the removal of H2S and / or mercaptans from a gas phase, the dialdehyde compound is present in the composition at a concentration of at least 10% by vol, alternatively at least 20% by vol, alternatively at least 50% by vol, alternatively at least 70% by vol, alternatively at least 90% by vol, and alternatively at least 95% by vol, where the nitrogen-containing removal agent can be used independently in similar proportions, but not necessarily in the same proportions as the dialdehyde.
    [0022] The cleaning compositions described herein may also include corrosion inhibitors including, but not limited to, phosphate esters, acetylenic alcohols, fatty acids and / or alkyl-substituted carboxylic acids and anhydrides, quaternary amines, sulfur phosphates oxygen and / or polyphosphate esters.
    [0023] The invention will now be illustrated with respect to certain examples which are not intended to limit the invention in any way, but simply to further illustrate it in certain specific embodiments. EXAMPLE 1
    [0024] Shown in Figure 2 is a graph of the difference between the H2S gas concentration sprayed through a brine solution and the existing H2S gas concentration over time after a fixed amount of glyoxal and triazine is separately co-jetted as compared to use of glyoxal and triazine each injected alone, but in equivalent amounts. That is, the use of 200 ppm monoethanolamine (MEA) triazine alone gives the largest initial drop in H2S, but H2S levels recovered more quickly. The use of 200 ppm of glyoxal alone does not cause such an initial drop in the H2S level, but suppresses H2S to a lower level for more than the 200 ppm of triazine alone. However, the use of 100 ppm of this triazine injected separately from 100 ppm of glyoxal ("cojected", but injected separately from each other, for a total of 200 ppm) gave the longest lasting results in which H2S was suppressed at a lower level over a longer period of time as compared to contacting the fluid with the separate components in equal total amounts.
    [0025] It can therefore be seen from the graph in Figure 2, that the separate co-injection of glyoxal and triazine synergistically increases the amount of clean H2S using glyoxal or triazine separately. The new cleaning method offers significantly increased efficiency due to the strong synergistic effect between the two components in liquid solutions. EXAMPLE 2
    [0026] Shown in Figure 3 are graphs comparing the results of using 200 ppm of a 1: 1 mixture of MEA triazine with glyoxal which was mixed for two minutes with the separate co-injection of 100 ppm MEA of triazine, followed by 100 ppm of glyoxal (the same graph as in Figure 2). It can be seen that when these components are injected as a mixture, the H2S level was initially reduced to only 1048 ppm as compared to the separate injection of the components where the H2S level was initially reduced to 1646 ppm. Additionally, it can be seen that when components are mixed before injection, H2S levels recover more quickly and completely as compared to the graph when the components are separately injected. This comparison shows that it is better not to mix the components before the injection; a reaction product resulting from the mixture is inferred in a non-limiting embodiment.
    [0027] In the preceding specification, the invention has been described with reference to its specific embodiments, and has been shown to be effective in providing methods and compositions for cleaning H2S and / or mercaptans from aqueous fluids, hydrocarbon fluids, gas phases and / or combinations of these. However, it will be evident that various modifications and changes can be made to it without departing from the scope of the invention as stated in the appended claims. Consequently, the specification is to be related in an illustrative sense rather than in a restrictive sense. For example, specific dialdehydes, nitrogen-containing removal agents, and optional surfactants and solvents fall within the claimed parameters, but not specifically identified or attempted on a particular composition or method, are expected to be within the scope of this invention.
    [0028] The words "comprising" and "comprises", as used throughout all claims, are interpreted "including, but not limited to".
    [0029] The present invention can adequately comprise, consist or consist essentially of the disclosed elements and can be practiced in the absence of an undisclosed element. For example, in the method for cleaning hydrogen sulfide and / or mercaptans from a fluid selected from the group consisting of an aqueous phase, a gas phase, a hydrocarbon phase and mixtures thereof, the method may consist of, or consist essentially of, of, contact the fluid separately with: an effective amount to synergistically clean hydrogen sulfide and / or mercaptans from at least one dialdehyde, and an effective amount to synergistically clean hydrogen sulfide and / or mercaptans from at least one removal agent containing nitrogen, where at least one dialdehyde and at least one nitrogen-containing removal agent are not mixed together prior to each fluid contact. In such a method, the amount of hydrogen sulfide and / or clean mercaptans is greater as compared to a method of contacting the fluid with at least one dialdehyde alone and a method of contacting the fluid with at least one nitrogen-containing removal agent alone in equal total amounts depending on the combined effective amount.
    权利要求:
    Claims (5)
    [0001]
    1. Method for removing sulfur-containing compounds selected from the group consisting of hydrogen sulfide, mercaptans and combinations thereof, from the medium, characterized by the fact that it comprises: (a) contacting the medium separately with: an effective amount to remove synergistically the sulfur-containing compound of at least one dialdehyde at least comprising glyoxal, and an amount effective to synergistically remove the sulfur-containing compound from at least one nitrogen-containing removal agent comprising at least one triazine, the at least one dialdehyde and the hair less a nitrogen-containing removal agent are not mixed together before each contact of the medium, with the combined effective amount of dialdehyde and effective amount of nitrogen-containing removal agent in the fluid ranging from 1 to 100,000 ppm, with the medium being selected from the group consisting of an aqueous phase, a gas phase, a hydrocarbon phase, mixtures of a gas and / or an aqueous phase, and mixtures of a hydrocarbon phase with an aqueous phase, the medium also comprising the sulfur-containing compound; (b) removing an amount of the sulfur-containing compound that is greater compared to an amount removed by a method of contacting the medium with at least one dialect alone and a method of contacting the medium with at least one nitrogen-removing agent alone in total amounts equal to the combined effective amount.
    [0002]
    2. Method according to claim 1, characterized by the fact that at least one dialdehyde further comprises one or more members selected from the group consisting of malondialdehyde, succindialdehyde, glutaraldehyde, phthaldehyde and phthaldehyde, and combinations thereof.
    [0003]
    3. Method according to claim 1, characterized by the fact that the at least one nitrogen-containing removal agent further comprises one or more members selected from the group consisting of monomethylamine (MMA); monoethylamine dimethylamine; dipropylamine; tri methylamine; triethylamine; tripropylamine; monomethanolamine; dimethanolamine; trimethanolamine; triethanolamine; diethanolamine (DEA); triethanolamine (TEA); monoisopropanolamine; dipropanolamine; diisopropanolamine; tripropanolamine; N-methylethylamine; dimethyl ethanol amine; methyl diethanolamine; dimethylamino ethanol; diamines; imines; imidazolines; hydroxy-aminoalkyl ethers; morpholines; pyrrolidones; piperidones; alkylpyridines; aminomethylcyclopentylamine; 1-2-cyclohexanediamine, 1,5-pentanediamine, 1,6-hexanediamine, 1H-azepine, hexahydro; 1,4-butanediamine, products of the alkylene polyamine / formaldehyde reaction; bis- (tertiarybutylaminoethoxy) -ethane (BTEE); ethoxyethoxyethanol tertiaributylamine (EEETB); polyvalent metal chelates of aminocarboxylic acids; quaternary ammonium salts; polyethylene-dimine; polyalamine; polyvinylamine; aminocarbinols; aminals; bisoxazolidines; reaction products of ethylene diamine with formaldehyde; reaction product of N-butylamine formaldehyde; and combinations thereof.
    [0004]
    4. Method according to claim 1, characterized by the fact that the weight ratio of at least one dialdehyde to at least one nitrogen-containing removal agent ranges from 5/95 to 95/5, with at least one dialdehyde is in a 40% by weight aqueous solution.
    [0005]
    5. Method, according to claim 1, characterized by the fact that it is practiced in a refinery.
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    法律状态:
    2017-07-11| B03A| Publication of an application: publication of a patent application or of a certificate of addition of invention|
    2018-04-03| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2019-07-09| B06T| Formal requirements before examination|
    2020-04-28| B09A| Decision: intention to grant|
    2020-09-15| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 28/06/2012, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US201161502511P| true| 2011-06-29|2011-06-29|
    US61/502,511|2011-06-29|
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