JPH07258664A - Method for selectively removing hydrogen sulfide in gas - Google Patents
Method for selectively removing hydrogen sulfide in gasInfo
- Publication number
- JPH07258664A JPH07258664A JP6048705A JP4870594A JPH07258664A JP H07258664 A JPH07258664 A JP H07258664A JP 6048705 A JP6048705 A JP 6048705A JP 4870594 A JP4870594 A JP 4870594A JP H07258664 A JPH07258664 A JP H07258664A
- Authority
- JP
- Japan
- Prior art keywords
- gas
- absorption
- selectively removing
- absorbent
- hydrogen sulfide
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
Classifications
-
- Y02C10/04—
-
- Y02C10/06—
Abstract
Description
【０００１】[0001]
【産業上の利用分野】本発明はＣＯ2 （二酸化炭素）及
びＨ2 Ｓ（硫化水素）を含む各種のガスからＨ2 Ｓを選
択的に除去する方法に関する。さらに詳しくは、特定の
ヒンダードアミンの水溶液と前記ガスとを接触させてＨ
2 Ｓを選択的に除去する方法に関する。BACKGROUND OF THE INVENTION 1. Field of the Invention The present invention relates to a method for selectively removing H 2 S from various gases including CO 2 (carbon dioxide) and H 2 S (hydrogen sulfide). More specifically, by contacting an aqueous solution of a specific hindered amine with the gas, H 2
2 relates to a method of selectively removing S.
【０００２】[0002]
【従来の技術】石炭・重質油のガス化により得られるガ
ス、合成用ガス、水性ガス、天然ガスなど各種ガスに含
まれるＣＯ2 やＨ2 Ｓなどの酸性ガスを吸収剤を用いて
除去する技術は以前から知られている。これらの中に
は、単独吸収剤を使用するもの、混合吸収剤を使用する
もの、非水系吸収溶液を用いるもの、水系吸収溶液を用
いるものなど様々である。またＣＯ2 とＨ2 Ｓを含むガ
スからＨ2 Ｓのみを選択的に除去するもの、両者を除去
するものなどプロセスの目的に応じて吸収剤が選択され
ている。2. Description of the Related Art Acid gases such as CO 2 and H 2 S contained in various gases such as gas obtained by gasification of coal and heavy oil, synthesis gas, water gas, natural gas are removed by using an absorbent. Techniques for doing this have long been known. Among these, there are various types such as those using a single absorbent, those using a mixed absorbent, those using a non-aqueous absorbing solution, and those using an aqueous absorbing solution. In addition, an absorbent is selected according to the purpose of the process, such as one that selectively removes only H 2 S from a gas containing CO 2 and H 2 S, one that removes both of them.
【０００３】例えば、米国特許第４，５５３，９８４号
明細書には、メチルジエタノールアミン（以下、「ＭＤ
ＥＡ」と略す）の２０〜７０重量％水溶液を用いて、１
０〜１１０バールの圧力下、４０〜１００℃でＣＯ2 と
Ｈ2 Ｓを含む原料ガスと向流接触させ、原料ガス中のＣ
Ｏ2 とＨ2 Ｓを除去する方法が開示されている。For example, in US Pat. No. 4,553,984, methyldiethanolamine (hereinafter referred to as "MD
Abbreviated as "EA") with a 20 to 70% by weight aqueous solution.
Under a pressure of 0 to 110 bar, a countercurrent contact was made with a source gas containing CO 2 and H 2 S at 40 to 100 ° C. to obtain C in the source gas.
A method of removing O 2 and H 2 S is disclosed.
【０００４】ケミカルエンジニアリングサイエンス（ C
hemical Engineering Science ) ，４１巻，２号，４０
５〜４０８頁には、常温付近において、２−アミノ−２
−メチル−１−プロパノール（以下、「ＡＭＰ」と略
す）のようなヒンダードアミンとモノエタノールアミン
（以下、「ＭＥＡ」と略す）のような直鎖アミンの各水
溶液のＣＯ2 やＨ2 Ｓに対する吸収速度が報告されてい
る。Chemical Engineering Science (C
hemical Engineering Science), 41, No. 2, 40
On pages 5 to 408, 2-amino-2 at around room temperature.
Absorption of CO 2 and H 2 S of aqueous solutions of hindered amines such as -methyl-1-propanol (hereinafter abbreviated as "AMP") and linear amines such as monoethanolamine (hereinafter abbreviated as "MEA"). The speed is reported.
【０００５】エネルギー コンサーベーション インダ
ストリアル（ Energy ConservasionIndustrial ) ２０
〜２８頁，１９８４年には、ＣＯ2 を含むガス混合物か
らＨ 2 Ｓの選択的除去法が検討され、数％の水を含むＮ
−メチルピロリドン溶媒中のジメチルエタノールアミン
やＭＤＥＡが有望であるとされている。Energy Conservation Inder
STRIAL (Energy Conservasion Industrial) 20
Pp. 28, 1984, CO2Gas mixture containing
Et H 2A selective removal method of S has been studied, and N containing several% of water has been investigated.
-Dimethylethanolamine in methylpyrrolidone solvent
And MDEA are considered promising.
【０００６】エネルギー コンサーベーション インダ
ストリー アプライド テクニーク（ Energy Conserv
Industry Appl Techniques )２５３〜２６２頁，１９８
３年には、無水溶剤中の第３アミンとの反応性がＨ2 Ｓ
とＣＯ2 で異なるのを利用した両者の分離法が提案され
ている。アミンとしてはＭＤＥＡ、ジメチルエタノール
アミン、ジエチルエタノールアミン、１−ジメチルアミ
ノプロパン−２−オールなどが用いられている。Energy Conservation Industry Applied Technology
Industry Appl Techniques) pp. 253-262, 198.
In 3 years, the reactivity with tertiary amines in anhydrous solvents was changed to H 2 S.
A method for separating the two has been proposed by utilizing the difference between CO 2 and CO 2 . MDEA, dimethylethanolamine, diethylethanolamine, 1-dimethylaminopropan-2-ol and the like are used as amines.
【０００７】オイル ガス ジャーナル ７月１６日、
７０〜７６頁（１９８４）には、フレキソーブ ＳＥ
（ Flexsorb ＳＥ，商品名）が選択的にＨ2 Ｓを除去す
る吸収剤として適すること、フレキソーブ ＰＳ（商品
名 Flexsorb ＰＳ）がＣＯ2とＨ2 Ｓを共に除去する
のに適する吸収剤であること、フレキソーブ ＨＰ（商
品名 Flexsorb ＨＰ）がＣＯ2 を除去するのに適した
吸収剤である旨が記載されている。そしてＭＤＥＡの水
溶液に比べＨ2 Ｓの吸収能力が４０％優れているとされ
ている。しかし、これらの吸収剤を構成する化合物名は
明らかではなく、またこの吸収剤は非水系である。Oil Gas Journal July 16th,
70-76 (1984), Flexosorb SE
(Flexsorb SE, trade name) is suitable as an absorbent for selectively removing H 2 S, and Flexsorb PS (trade name Flexsorb PS) is a suitable absorbent for removing both CO 2 and H 2 S , Flexsorb HP (trade name: Flexsorb HP) is described as a suitable absorbent for removing CO 2 . And, it is said that the H 2 S absorption capacity is 40% better than the aqueous solution of MDEA. However, the names of the compounds constituting these absorbents are not clear, and the absorbents are non-aqueous.
【０００８】オイル ガス ジャーナル（ Oil & Gas J
ournal )８４巻，３９号，６１〜６５頁（１９８６）に
は、ＣＯ2 とＨ2 Ｓの除去には第３エタノールアミンで
あるＭＤＥＡとトリエタノールアミン、特にＭＤＥＡが
有用であると記載されている。またＭＤＥＡはＨ2 Ｓの
選択的吸収剤として用いられることが記載されている。Oil & Gas J
ournal) 84, 39, 61-65 (1986), describes that the tertiary ethanolamines MDEA and triethanolamine, particularly MDEA, are useful for removing CO 2 and H 2 S. There is. It is also described that MDEA is used as a selective absorbent of H 2 S.
【０００９】[0009]
【発明が解決しようとする課題】前記のようにＣＯ2 と
Ｈ2 Ｓを含むガスから、これらを除去する技術が種々提
案されている。しかし処理対象ガスからＣＯ2 を除去す
る必要性がなく、Ｈ2 Ｓをできるだけ選択的に除去する
ことが求められる分野があるが、このような目的に対
し、選択吸収性により優れ、かつ吸収剤の再生に要する
エネルギー的にも有利な吸収剤が求められている。この
ような用途においては、Ｈ2 ＳのほかにＣＯ 2 もよく吸
収することは、それだけ吸収剤の回収・再生工程でエネ
ルギーを必要とし、好ましくない。前記従来技術におい
ても選択的にＨ2 Ｓを除去する吸収剤が提案されている
が、吸収剤としてプロセス的に簡便な水溶液として用
い、またより一層選択性よくＨ2 Ｓを吸収でき、更にＨ
2 Ｓの吸収能力の高い吸収剤が求められている。[Problems to be Solved by the Invention] As described above, CO2When
H2Various technologies have been proposed to remove these from S-containing gas.
Is being proposed. However, if the target gas is CO2Remove
There is no need to2Remove S as selectively as possible
There are some fields that require
However, it is superior in selective absorption and required for regeneration of the absorbent.
There is a need for an energetically advantageous absorber. this
In such applications, H2CO in addition to S 2Suck well
It is only necessary to collect energy in the absorbent recovery and regeneration process.
It is not desirable because it requires rugies. The conventional technology smell
But selectively H2An absorbent that removes S has been proposed
However, as an absorbent, it can be used as an aqueous solution that is easy to process.
H, which is even more selective2Can absorb S, and further H
2There is a demand for an absorbent having a high S absorption capacity.
【００１０】[0010]
【課題を解決するための手段】本発明者らは前記課題に
鑑み、ＣＯ2 とＨ2 Ｓを含む処理対象ガスから選択性高
くＨ2 Ｓを除去できる吸収剤について鋭意検討した結
果、特定のヒンダードアミンの水溶液が特に有効である
との知見を得て、本発明を完成させることができた。す
なわち本発明は、第３ブチルジエタノールアミン、トリ
イソプロパノールアミン、トリエチレンジアミン及び２
−ジメチルアミノ−２−メチル−１−プロパノールの群
から選ばれるヒンダードアミンの水溶液とＣＯ2 とＨ2
Ｓを含む混合ガスとを接触させて、前記混合ガス中のＨ
2 Ｓを選択的に除去する方法である。In view of the above-mentioned problems, the inventors of the present invention have made earnest studies on an absorbent capable of removing H 2 S from a gas to be treated containing CO 2 and H 2 S with high selectivity. The present invention has been completed by finding that an aqueous solution of hindered amine is particularly effective. That is, the present invention relates to tertiary butyldiethanolamine, triisopropanolamine, triethylenediamine and 2
- an aqueous solution of hindered amine selected from the group consisting of dimethylamino-2-methyl-1-propanol and CO 2 and H 2
The mixed gas containing S is brought into contact with the H gas in the mixed gas.
This is a method of selectively removing 2 S.
【００１１】本発明で吸収剤として使用する化合物は第
３ブチルジエタノールアミン｛ｔ−ＢｕＮ（ＣＨ2 ＣＨ
2 ＯＨ）2 、以下「ＢＤＥＡ」と略す｝、トリイソプロ
パノールアミン｛〔ＣＨ3 ＣＨ（ＯＨ）ＣＨ2 〕3 Ｎ、
以下「ＴＩＰＡ」と略す｝、トリエチレンジアミン｛Ｎ
（ＣＨ2 ）6 Ｎ、以下「ＴＥＤＡ」と略す｝及び２−ジ
メチルアミノ−２−メチル−１−プロパノール｛（ＣＨ
3 ）2 ＮＣ（ＣＨ3 ） 2 ＣＨ2 ＯＨ、以下「ＤＭＡＭ
Ｐ」と略す｝であり、これらは各単独で用いることがで
きるほか、互いに混合して用いることができる。これら
の中では、Ｈ2 Ｓの選択吸収性の点からＴＩＰＡ、ＴＥ
ＤＡ、ＢＤＥＡが好ましく、またＨ2 Ｓの吸収能力の点
からＤＭＡＭＰ及びＴＥＤＡが好ましい。The compounds used as absorbents in the present invention are
3-Butyldiethanolamine {t-BuN (CH2CH
2OH)2, Abbreviated as “BDEA” hereinafter, triisopro
Panolamine {[CH3CH (OH) CH2]3N,
Hereinafter abbreviated as "TIPA"}, triethylenediamine {N
(CH2)6N, hereinafter abbreviated as "TEDA"} and 2-di
Methylamino-2-methyl-1-propanol {(CH
3)2NC (CH3) 2CH2OH, hereinafter "DAM
Abbreviated as “P”}, and these can be used alone.
Besides, they can be mixed with each other. these
In the2From the point of selective absorption of S, TIPA, TE
DA and BDEA are preferred, and H2Points of S absorption capacity
To DMAMP and TEDA are preferred.
【００１２】本発明で用いる吸収剤溶液は、前記ヒンダ
ードアミンの水溶液であり、そのヒンダードアミンの濃
度は通常１５〜７５重量％である。また本発明で用いる
水溶液には、必要に応じて腐蝕防止剤、劣化防止剤など
が加えられる。本発明において、対象ガスと水溶液の接
触温度は通常３０〜７０℃の範囲である。対象ガスの種
類にもよるが、接触時の対象ガスの圧力は通常大気圧〜
１５０ｋｇ／ｃｍ2 Ｇの範囲である。The absorbent solution used in the present invention is an aqueous solution of the hindered amine, and the concentration of the hindered amine is usually 15 to 75% by weight. In addition, a corrosion inhibitor, a deterioration inhibitor, etc. are added to the aqueous solution used in the present invention, if necessary. In the present invention, the contact temperature between the target gas and the aqueous solution is usually in the range of 30 to 70 ° C. Depending on the type of target gas, the pressure of the target gas at the time of contact is usually atmospheric pressure ~
It is in the range of 150 kg / cm 2 G.
【００１３】本発明において「Ｈ2 Ｓの選択的吸収」と
は、必ずしもＣＯ2 を全く吸収しないということではな
く、Ｈ2 Ｓの吸収速度に比べてＣＯ2 の吸収速度が著し
く小さいことを意味する。但し、吸収速度は処理対象ガ
スの組成、吸収条件などにより異なる。従って、本発明
においては選択吸収性でその選択性を評価することとし
た。ここで選択吸収性とは吸収条件下において、吸収液
中の吸収されたＨ2 Ｓのモル数を同ＣＯ2 のモル数で除
し、さらにその値を処理対象ガス中のＨ2 Ｓのモル数と
ＣＯ2 のモル数の比で除したものである。本発明によれ
ば、従来使用されていたＭＤＥＡに比べ選択吸収性は高
い。In the present invention, "selective absorption of H 2 S" does not necessarily mean that CO 2 is not absorbed at all, but means that the absorption rate of CO 2 is significantly smaller than the absorption rate of H 2 S. To do. However, the absorption rate differs depending on the composition of the gas to be treated, the absorption conditions and the like. Therefore, in the present invention, the selectivity is evaluated by the selective absorption. Here, the selective absorbability is obtained by dividing the number of moles of H 2 S absorbed in the absorbing solution by the number of moles of CO 2 under the absorbing condition, and further calculating the value by the number of moles of H 2 S in the gas to be treated. Number divided by the ratio of the number of moles of CO 2 . According to the present invention, the selective absorption is higher than that of MDEA which has been conventionally used.
【００１４】本発明によるＨ2 Ｓを選択的に除去する方
法は、各種対象ガスに適用することができる。例えば石
炭・重質油ガス化ガス、合成ガス、水性ガス、天然ガ
ス、石油精製ガスなどをあげることができる。さらに、
石油精製に伴うクラウステールガス（ Claus tail gas
) 中に含まれるＨ2 Ｓの除去などに応用することもで
きる。The method for selectively removing H 2 S according to the present invention can be applied to various target gases. For example, coal / heavy oil gasification gas, synthesis gas, water gas, natural gas, petroleum refined gas, etc. can be mentioned. further,
Claus tail gas associated with oil refining
) It can also be applied to removal of H 2 S contained in
【００１５】本発明の方法で採用できるプロセスは、特
に限定されないが、その一例について図１によって説明
する。図１では主要設備のみ示し、付属設備は省略し
た。図１において、処理対象ガスは供給ライン１０１に
より吸収塔１０２の下部に導入され、上部より降下する
吸収液と充填部において気液接触し、吸収処理されたガ
スは処理ガス取り出しライン１０８から系外に取り出さ
れる。Ｈ2 Ｓ及びＣＯ2 を吸収した吸収液は吸収液の取
り出しライン１０３により吸収塔塔底から取り出され、
熱交換器１０４で加熱されて、吸収液の再生塔１０５に
導入される。再生塔１０５に至る過程で、フラッシュド
ラムによりＨ2 Ｓの一部を分離しても構わない。再生塔
１０５では下部に設けられたリボイラー１０９の熱源に
より、吸収液が再生され、再生吸収液は循環ライン１０
６により、熱交換器１０４及び１０７を経由して吸収塔
１０２に循環される。一方、吸収液の再生により取り出
されたＨ2 ＳとＣＯ2 を含むガスは、その取り出しライ
ン１１０から次の処理工程に導かれる。The process that can be used in the method of the present invention is not particularly limited, but an example thereof will be described with reference to FIG. In FIG. 1, only the main equipment is shown and the auxiliary equipment is omitted. In FIG. 1, the gas to be treated is introduced into the lower part of the absorption tower 102 by the supply line 101, and comes into gas-liquid contact with the absorbing liquid descending from the upper part in the filling part, and the gas subjected to the absorption treatment is discharged from the treated gas extraction line 108 to the outside of the system. Taken out. The absorption liquid which has absorbed H 2 S and CO 2 is taken out from the bottom of the absorption tower through the absorption liquid take-out line 103,
It is heated in the heat exchanger 104 and introduced into the absorption liquid regeneration tower 105. In the process of reaching the regeneration tower 105, a part of H 2 S may be separated by a flash drum. In the regeneration tower 105, the absorption liquid is regenerated by the heat source of the reboiler 109 provided in the lower part, and the regenerated absorption liquid is circulated in the circulation line 10
6, is circulated to the absorption tower 102 via the heat exchangers 104 and 107. On the other hand, the gas containing H 2 S and CO 2 extracted by the regeneration of the absorbing liquid is introduced from the extraction line 110 to the next processing step.
【００１６】[0016]
【実施例】以下、実施例により本発明を具体的に説明す
る。 （実施例１〜４、比較例１）実施例に用いた装置を図２
に示す。図２において、ボンベ２０１からＨ2 Ｓ／ＣＯ
2 ／Ｎ2 の体積比１／５０／４９の混合ガスを減圧弁２
０２、流量調節計２０３を経由して５００ｃｃ用セパラ
ブルフラスコ２０４に供給される。セパラブルフラスコ
には２０７で示される吸収液：３００ｇ（吸収剤総量が
１．０１モル）を入れ、前記混合ガスがスターラー２０
６の攪拌下にバブリングするように配置されている。ま
たセパラブルフラスコ内の吸収液の温度は温度調節器２
０８を具備した水槽２０５にて５０℃に保持されるよう
になっている。バブリングと攪拌によりガス成分が吸収
液に吸収された後の出口ガスは、サンプリング部２０９
へ一部導かれてガスクロマトグラフ法による分析に供さ
れ、残りは廃棄部２１０より系外に廃棄されるようにな
っている。EXAMPLES The present invention will be specifically described below with reference to examples. (Examples 1 to 4 and Comparative Example 1) FIG.
Shown in. In FIG. 2, from the cylinder 201 to H 2 S / CO
2 / N 2 volume ratio 1/50/49 mixed gas mixed pressure reducing valve 2
02, and is supplied to the 500 cc separable flask 204 via the flow rate controller 203. The separable flask was charged with 300 g of the absorbing liquid indicated by 207 (total amount of the absorbing agent was 1.01 mol), and the mixed gas was stirred by the stirrer 20.
6 is arranged so as to bubble under stirring. The temperature of the absorbent in the separable flask is controlled by the temperature controller 2
It is designed to be kept at 50 ° C. in a water tank 205 equipped with 08. The outlet gas after the gas components have been absorbed by the absorbing liquid by bubbling and stirring is the sampling unit 209.
Is partially introduced to the gas chromatographic method for analysis, and the rest is discarded from the waste unit 210 to the outside of the system.
【００１７】混合ガスを１Ｎｍ3 ／分の流量で吸収液に
導き、同一攪拌条件で吸収開始から出口ガス中のＨ2 Ｓ
の濃度が供給混合ガス中の濃度に達した時点（Ｈ2 Ｓ破
過到達時点）までのＨ2 Ｓの吸収量、及び選択吸収性を
調べた。なお選択吸収性としては、Ｈ2 Ｓ破過到達時点
のＨ2 ＳとＣＯ2 の吸収モル量の比を原料ガス中の両者
の比（１／５０）で除した値である。得られた結果を表
１に示した。The mixed gas was introduced into the absorbing liquid at a flow rate of 1 Nm 3 / min, and H 2 S in the outlet gas from the start of absorption under the same stirring conditions.
The amount of H 2 S absorbed and the selective absorbability until the time when the concentration of H 2 S reached the concentration in the supplied mixed gas (time of reaching H 2 S breakthrough) were examined. The selective absorptivity is a value obtained by dividing the ratio of the molar amounts of H 2 S and CO 2 absorbed when the H 2 S breakthrough is reached by the ratio (1/50) of both in the raw material gas. The obtained results are shown in Table 1.
【００１８】[0018]
【表１】 [Table 1]
【００１９】表１から分かるように、本発明で使用する
ヒンダードアミンはＴＥＤＡとＤＭＡＭＰを除き、従来
から選択的Ｈ2 Ｓ吸収剤として使用されたきたＭＤＥＡ
に比べＨ2 Ｓの吸収量は小さいが、何れも選択吸収性の
点でＭＤＥＡよりも遙かに優れることが分かる。さらに
ＴＥＤＡとＤＭＡＭＰはＨ2 Ｓの選択吸収性のみならず
Ｈ2 Ｓの吸収量がＭＤＥＡよりも大きいことが分かる。As can be seen from Table 1, the hindered amines used in the present invention, with the exception of TEDA and DMAMP, have been conventionally used as selective H 2 S absorbers in MDEA.
Although the absorption amount of H 2 S is smaller than that of the above, it is understood that both are far superior to MDEA in terms of selective absorption. Further TEDA and DMAMP absorption of H 2 S not only selective absorption of H 2 S is found to be greater than MDEA.
【００２０】[0020]
【発明の効果】以上詳細に述べたごとく、本発明の方法
によれば、従来の吸収剤ＭＤＥＡを用いる場合と比べ、
Ｈ2 ＳとＣＯ2 を含む原料ガスからＨ2 Ｓをより選択的
に除去することができる。As described in detail above, according to the method of the present invention, compared with the case of using the conventional absorbent MDEA,
From a feed gas containing H 2 S and CO 2 can be more selective removal of H 2 S.
【図１】本発明で採用できるプロセスの一例を示す図。FIG. 1 is a diagram showing an example of a process that can be adopted in the present invention.
【図２】本発明の実施例で用いた試験装置。FIG. 2 is a test apparatus used in an example of the present invention.
───────────────────────────────────────────────────── フロントページの続き (51)Int.Cl.6 識別記号 庁内整理番号 ＦＩ 技術表示箇所 Ｂ０１Ｄ 53/34 １２７ Ｂ (72)発明者 光岡 薫明 広島県広島市西区観音新町四丁目６番22号 三菱重工業株式会社広島研究所内 (72)発明者 飯島 正樹 東京都千代田区丸の内二丁目５番１号 三 菱重工業株式会社本社内─────────────────────────────────────────────────── ─── Continuation of the front page (51) Int.Cl. 6 Identification number Reference number within the agency FI Technical display location B01D 53/34 127 B (72) Inventor Kaoru Mitsuoka 4-6 Kannon Shinmachi, Nishi-ku, Hiroshima city, Hiroshima prefecture 22 Mitsubishi Heavy Industries, Ltd. Hiroshima Research Laboratory (72) Inventor Masaki Iijima 2-5-1, Marunouchi, Chiyoda-ku, Tokyo Sanryo Heavy Industries Co., Ltd.
Claims (1)
ソプロパノールアミン、トリエチレンジアミン及び２−
ジメチルアミノ−２−メチル−１−プロパノールの群か
ら選ばれるヒンダードアミンの水溶液とＣＯ2 とＨ2 Ｓ
を含むガスとを接触させることを特徴とする前記ガス中
のＨ2 Ｓを選択的に除去する方法。1. Tertiary butyldiethanolamine, triisopropanolamine, triethylenediamine and 2-
Aqueous solution of hindered amine selected from the group of dimethylamino-2-methyl-1-propanol and CO 2 and H 2 S
A method of selectively removing H 2 S in the gas, which comprises contacting with a gas containing
Priority Applications (7)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| JP6048705A JP2966719B2 (en) | 1994-03-18 | 1994-03-18 | Method for selectively removing hydrogen sulfide in gas |
| EP95103451A EP0672446B1 (en) | 1994-03-18 | 1995-03-10 | Method for the removal of hydrogen sulfide present in gases |
| EP97115974A EP0827772A3 (en) | 1994-03-18 | 1995-03-10 | Method for the removal of carbon dioxide and hydrogen sulfide from a gas containing these gases |
| DE69528785T DE69528785T2 (en) | 1994-03-18 | 1995-03-10 | Process for removing hydrogen sulfide from gases |
| US08/405,628 US5609840A (en) | 1994-03-18 | 1995-03-15 | Method for the removal of hydrogen sulfide present in gases |
| CN95103506A CN1069551C (en) | 1994-03-18 | 1995-03-17 | Method for the removal of hydrogen sulfide present in gases |
| US08/742,747 US5750083A (en) | 1994-03-18 | 1996-11-01 | Method for the removal of hydrogen sulfide present in gases |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| JP6048705A JP2966719B2 (en) | 1994-03-18 | 1994-03-18 | Method for selectively removing hydrogen sulfide in gas |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| JPH07258664A true JPH07258664A (en) | 1995-10-09 |
| JP2966719B2 JP2966719B2 (en) | 1999-10-25 |
Family
ID=12810741
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| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| JP6048705A Expired - Lifetime JP2966719B2 (en) | 1994-03-18 | 1994-03-18 | Method for selectively removing hydrogen sulfide in gas |
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| Country | Link |
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| JP (1) | JP2966719B2 (en) |
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2013084402A1 (en) * | 2011-12-08 | 2013-06-13 | 川崎重工業株式会社 | Method and apparatus for separating hydrogen sulfide and hydrogen production system using same |
| JP2016129877A (en) * | 2015-01-14 | 2016-07-21 | 株式会社東芝 | Acid gas absorbent, acid gas removal method and acid gas removal device |
| JP2019507209A (en) * | 2016-01-05 | 2019-03-14 | ドルフ ケタール ケミカルズ （インディア）プライヴェート リミテッド | Hydrogen sulfide scavenging additive composition and method of use thereof |
-
1994
- 1994-03-18 JP JP6048705A patent/JP2966719B2/en not_active Expired - Lifetime
Cited By (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2013084402A1 (en) * | 2011-12-08 | 2013-06-13 | 川崎重工業株式会社 | Method and apparatus for separating hydrogen sulfide and hydrogen production system using same |
| JP2013119503A (en) * | 2011-12-08 | 2013-06-17 | Kawasaki Heavy Ind Ltd | Method and device for separating hydrogen sulfide and hydrogen manufacturing system using the same |
| AU2012347153B2 (en) * | 2011-12-08 | 2015-09-24 | Kawasaki Jukogyo Kabushiki Kaisha | Method and device for separating hydrogen sulfide and hydrogen production system using the same |
| US9365423B2 (en) | 2011-12-08 | 2016-06-14 | Kawasaki Jukogyo Kabushiki Kaisha | Method and device for separating hydrogen sulfide and hydrogen production system using the same |
| JP2016129877A (en) * | 2015-01-14 | 2016-07-21 | 株式会社東芝 | Acid gas absorbent, acid gas removal method and acid gas removal device |
| JP2019507209A (en) * | 2016-01-05 | 2019-03-14 | ドルフ ケタール ケミカルズ （インディア）プライヴェート リミテッド | Hydrogen sulfide scavenging additive composition and method of use thereof |
Also Published As
| Publication number | Publication date |
|---|---|
| JP2966719B2 (en) | 1999-10-25 |
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