JPH05245339A - Method for removing carbon dioxide and sulfur compounds in combustion exhaust gas - Google Patents
Method for removing carbon dioxide and sulfur compounds in combustion exhaust gasInfo
- Publication number
- JPH05245339A JPH05245339A JP4045245A JP4524592A JPH05245339A JP H05245339 A JPH05245339 A JP H05245339A JP 4045245 A JP4045245 A JP 4045245A JP 4524592 A JP4524592 A JP 4524592A JP H05245339 A JPH05245339 A JP H05245339A
- Authority
- JP
- Japan
- Prior art keywords
- desulfurization
- exhaust gas
- sox
- combustion exhaust
- gas
- 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
-
- 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
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A50/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE in human health protection, e.g. against extreme weather
- Y02A50/20—Air quality improvement or preservation, e.g. vehicle emission control or emission reduction by using catalytic converters
-
- 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
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
- Y02C20/00—Capture or disposal of greenhouse gases
- Y02C20/40—Capture or disposal of greenhouse gases of CO2
-
- 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
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E20/00—Combustion technologies with mitigation potential
- Y02E20/32—Direct CO2 mitigation
Landscapes
- Chimneys And Flues (AREA)
- Treating Waste Gases (AREA)
Abstract
Description
【０００１】[0001]
【産業上の利用分野】本発明は燃焼排ガス中に含まれる
ＳＯｘ（硫黄酸化物）とＣＯ2 （二酸化炭素）を除去す
る方法に関する。さらに詳しくは、ＣＯ2 を除去すると
共に、副次的にもＳＯｘを発生させることなく燃焼排ガ
スからほぼ完全にＳＯｘを除去できる燃焼排ガスからＳ
ＯｘとＣＯ2 を共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 removing SOx (sulfur oxide) and CO 2 (carbon dioxide) contained in combustion exhaust gas. More specifically, it is possible to remove CO 2 from the combustion exhaust gas and to almost completely remove SOx from the combustion exhaust gas without secondary generation of SOx.
It relates to a method for removing both Ox and CO 2 .
【０００２】[0002]
【従来の技術】近年、地球の温暖化現象の原因の一つと
して、ＣＯ2 による温室効果が指摘され、地球環境を守
る上で国際的にもその対策が急務となってきた。ＣＯ2
の発生源としては化石燃料を燃焼させるあらゆる人間の
活動分野に及び、その排出抑制への要求が一層強まる傾
向にある。これに伴い大量の化石燃料を使用する火力発
電所などの動力発生設備を対象に、ボイラの燃焼排ガス
をアルカノールアミン水溶液等と接触させて燃焼排ガス
中のＣＯ2 を除去し、回収する方法および回収されたＣ
Ｏ2 を大気へ放出することなく貯蔵する方法が精力的に
研究されている。2. Description of the Related Art In recent years, the greenhouse effect of CO 2 has been pointed out as one of the causes of the global warming phenomenon, and there is an urgent need to take countermeasures internationally in order to protect the global environment. CO 2
As the source of the emission of carbon dioxide, it extends to all human activity fields that burn fossil fuels, and there is a tendency for the demand for emission control to increase. Along with this, for a power generation facility such as a thermal power plant that uses a large amount of fossil fuel, a method and a method of recovering by removing CO 2 in the combustion exhaust gas by bringing the combustion exhaust gas of the boiler into contact with an alkanolamine aqueous solution, etc. C
Methods for storing O 2 without releasing it to the atmosphere have been vigorously studied.
【０００３】また、化石燃料はその種類により程度の差
はあるものの、燃焼によりＳＯｘやＮＯｘ（窒素酸化
物）などの汚染物質を発生させ、これらは大気汚染や酸
性雨の原因とされ、そ排出基準が強化される傾向にあ
る。特に大量に化石燃料を消費する大都市やその周辺に
おいては、火力発電所、工場、自動車等からのＳＯｘや
ＮＯｘの排出を総量で規制しようとする傾向にある。従
って、火力発電所を例にとるならば、既存の設備からの
排出規制の強化はもちろん、今後新設される設備におい
てはこれらの汚染物質の排出を極力抑えるか、あるいは
ほとんど排出しない程度の対策が講じたものでなけれ
ば、前記総量規制のため建設できないという事態になり
つつある。Further, although fossil fuels vary in degree depending on their types, combustion produces pollutants such as SOx and NOx (nitrogen oxides), which are the causes of air pollution and acid rain, and their emission. Standards tend to be strengthened. Particularly in large cities and their surroundings that consume large amounts of fossil fuels, there is a tendency to control the total amount of SOx and NOx emissions from thermal power plants, factories, automobiles and the like. Therefore, taking a thermal power plant as an example, not only will emission regulations from existing facilities be tightened, but measures will be taken to prevent emissions of these pollutants as much as possible or to prevent them from being emitted in newly installed facilities in the future. If it is not taken, it is becoming a situation where construction cannot be done due to the total amount regulation.
【０００４】排煙脱硫法に関しては、従来より各種の乾
式法や湿式法が提案されているが、石灰石（炭酸カルシ
ウム）粉末の水スラリにＳＯｘを吸収させ、石こうにし
て回収するいわゆる湿式石灰−石こう法が代表的なもの
である。Regarding the flue gas desulfurization method, conventionally, various dry methods and wet methods have been proposed, but a so-called wet lime-type in which SOx is absorbed in a water slurry of limestone (calcium carbonate) powder and recovered in gypsum. The gypsum method is typical.
【０００５】[0005]
【発明が解決しようとする課題】燃焼排ガスからＣＯ2
を除去すると共にＳＯｘなども除去するためには、それ
ぞれの除去工程を組み合わせ、脱硫処理した後に脱ＣＯ
2 処理することにより達成することができる。そして条
件を選択すれば、脱ＣＯ2 処理ガス中のＳＯｘの濃度を
ほぼ完全な脱硫処理レベルであって、前記総量規制にも
十分対応できる１ｐｐｍ以下にまで効率よくＳＯｘの排
出を下げることが可能である。THE INVENTION Problems to be Solved] CO 2 from combustion exhaust gas
In order to remove not only SOx but also SOx, etc., the respective removal steps are combined, desulfurization treatment is performed, and then CO removal is performed.
2 can be achieved by processing. If conditions are selected, the SOx concentration in the CO 2 removal processing gas can be effectively reduced to 1 ppm or less, which is at a level of almost complete desulfurization processing and can fully comply with the total amount regulation. Is.
【０００６】このような燃焼排ガスの処理方法において
は、多かれ少なかれ下記のような脱ＣＯ2 工程からのリ
クレーミング操作によるスラッジの発生は通常避けられ
ない。スラッジの内容物の詳細については不明である
が、脱硫工程で除去されずに脱硫処理ガス中に残存する
ＳＯｘが脱ＣＯ2 工程においてアルカノールアミンと反
応（モノアミンでは前者１モルに対し、後者が２モル結
合）して生じた安定塩が多分に含まれている。同様に脱
硝工程で除去されなかったＮＯｘの一部もこの安定塩を
形成しているものと考えられる。この安定塩はＣＯ2 を
吸収したアルカノールアミンからアルカノールアミンを
再生する過程でも、通常の条件下では再生しないため、
脱ＣＯ2 工程の系内に徐々に蓄積されることとなる。そ
して前記のように脱ＣＯ2 工程内に設けられる処理設備
からスラッジとして系外に排出される。このスラッジの
有効利用方法は今のところなく、別途焼却処理されてい
るのが実状である。しかし、脱硫処理前の燃焼排ガス中
のＳＯｘに比べれば微々たる量とはいえ、スラッジの焼
却により副次的に再びＳＯｘ等を発生させることとな
り、前記総量規制の観点からもこの改善が望まれてい
た。In such a method for treating combustion exhaust gas, the generation of sludge due to the reclaiming operation from the CO 2 removal step as described below is usually unavoidable. Although details of the content of the sludge are unknown, the SOx remaining in the desulfurization treatment gas without being removed in the desulfurization process reacts with the alkanolamine in the CO 2 removal process (the former amine is 1 mol and the latter is 2 mol). The stable salt formed by the (molar bond) is probably contained. Similarly, it is considered that a part of NOx not removed in the denitration step also forms this stable salt. Since this stable salt does not regenerate under normal conditions even in the process of regenerating alkanolamine from alkanolamine that has absorbed CO 2 ,
It is gradually accumulated in the system of the CO 2 removal process. Then, as described above, it is discharged out of the system as sludge from the treatment facility provided in the CO 2 removal step. There is no effective method of using this sludge so far, and it is the fact that it is incinerated separately. However, although it is a slight amount compared to SOx in the combustion exhaust gas before desulfurization, SOx and the like are secondarily generated again by sludge incineration, and this improvement is also desired from the viewpoint of the total amount regulation. Was there.
【０００７】[0007]
【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、燃焼排ガス中のＳＯｘとＣＯ2 を共に除去する際
に発生するスラッジの取扱いについて鋭意検討した結
果、そのスラッジを、脱硫や脱ＣＯ2 処理をすべき燃焼
ガスを発生させる燃焼装置で燃焼させることが特に有効
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。In view of the above problems, the inventors of the present invention have earnestly studied the handling of sludge generated when removing both SOx and CO 2 in combustion exhaust gas, and as a result, The present invention has been completed based on the finding that it is particularly effective to combust with a combustor that generates a combustion gas to be subjected to CO 2 removal treatment.
【０００８】すなわち、本発明の第一は燃焼装置から発
生するＳＯｘを含む燃焼排ガスを脱硫処理する工程およ
び前記脱硫処理されたガスをアルカノールアミン水溶液
と接触させてＣＯ2 を除去する脱ＣＯ2 工程により燃焼
排ガス中のＣＯ2 とＳＯｘを除去する方法において、脱
ＣＯ2 工程から発生するリクレーマよりのスラッジを前
記燃焼装置で燃焼させることを特徴とする燃焼排ガス中
のＣＯ2 とＳＯｘを除去する方法である。That is, the first aspect of the present invention is a step of desulfurizing combustion exhaust gas containing SOx generated from a combustion apparatus and a step of removing CO 2 by contacting the desulfurized gas with an aqueous alkanolamine solution to remove CO 2. method of removing in a method for removing CO 2 and SOx in the combustion exhaust gas, the CO 2 and SOx in combustion exhaust gas, characterized in that the combustion of sludge from reclaimer generated from de-CO 2 process in the combustion device by Is.
【０００９】また、本発明の第二は前記第一において、
脱硫処理する工程により脱硫処理ガス中のＳＯｘ濃度が
５〜１０ｐｐｍの範囲内になるように脱硫処理したの
ち、前記脱硫処理ガスを脱ＣＯ2 工程によりＣＯ2 を除
去すると共に脱ＣＯ2 処理ガス中のＳＯｘの濃度が１ｐ
ｐｍ以下となるようにＳＯｘを除去することを特徴とす
る燃焼排ガス中のＣＯ2 とＳＯｘを除去する方法であ
る。A second aspect of the present invention is the above first aspect,
After desulfurization treatment so that SOx concentration in the desulfurized gas made within the scope of 5~10ppm by the step of desulfurization treatment, de-CO 2 process gas to remove the CO 2 the desulfurized gas with de CO 2 step SOx concentration is 1p
It is a method for removing CO 2 and SOx in a combustion exhaust gas, which is characterized in that SOx is removed so as to be pm or less.
【００１０】[0010]
【作用】本発明の方法が適用される燃焼排ガスの処理工
程の一例を図１に示す。図１において、Ａは石炭、ナフ
サ、重油などを燃料とするボイラであり、Ｂは脱硫工程
であり、触媒の存在下でアンモニアを注入して窒素酸化
物（ＮＯｘ）を還元し、窒素と酸素に分解するものが例
示される。Ｃは電気集塵機等の集塵工程、Ｄは脱硫工
程、Ｅは脱ＣＯ2 工程、Ｆは煙突、Ｇはスラッジ移送設
備である。FIG. 1 shows an example of a process for treating combustion exhaust gas to which the method of the present invention is applied. In FIG. 1, A is a boiler that uses coal, naphtha, heavy oil, etc. as fuel, and B is a desulfurization process, in which ammonia is injected in the presence of a catalyst to reduce nitrogen oxides (NOx), and nitrogen and oxygen are added. The thing that decomposes into is illustrated. C is a dust collecting process such as an electric dust collector, D is a desulfurization process, E is a CO 2 removal process, F is a chimney, and G is a sludge transfer facility.
【００１１】本発明に採用される脱硫工程は、特に限定
されていが、後述の理由により燃焼排ガスを処理して処
理ガス中のＳＯｘの濃度を１０ｐｐｍ以下に抑えること
ができるものが好ましい。このような高性能脱硫工程と
して、本願出願人が先に提案した「高性能排煙脱硫方
法」（特願平３〜２０３０４号）を採用することが特に
好ましい。これを図２に示す。The desulfurization step employed in the present invention is not particularly limited, but it is preferable to treat the combustion exhaust gas so that the concentration of SOx in the treated gas can be suppressed to 10 ppm or less for the reason described below. As such a high-performance desulfurization step, it is particularly preferable to employ the “high-performance flue gas desulfurization method” proposed by the applicant of the present application (Japanese Patent Application No. 3-20304). This is shown in FIG.
【００１２】図２において、燃焼排ガス２００は第１吸
収塔２０１に導かれ、ポンプＰ1 、第１循環ライン２０
５を介して第１ノズル２０３より噴霧される第１液溜２
０９の吸収剤であるスラリＳ1 （１％以下の炭酸カルシ
ウムを含む石こうスラリ）と接触（例えば並流接触）さ
せられ、必要に応じて設けられた第１充填層２０７を通
過し、この間にスラリＳ1 中の炭酸カルシウムによって
脱硫されつつスラリＳ 1 と共に下降し、スラリＳ1 は第
１液溜２０９に貯留され、脱硫された排ガスは例えば第
１液溜２０９と第２液溜２１０を分割する分割板２１４
の上部空間を通って第２吸収塔２０２の方へ通過してい
く。In FIG. 2, the combustion exhaust gas 200 has the first intake gas.
Pumped to the collecting tower 201 and pump P1, First circulation line 20
The first liquid reservoir 2 sprayed from the first nozzle 203 via
Slurry S which is the absorbent of 091(Calcium carbonate less than 1%
Contact with gypsum slurries containing um) (eg co-current contact)
Through the first filling layer 207, which is provided as necessary.
Slurry S in the meantime1By calcium carbonate inside
Slurry S being desulfurized 1Descends with slurry S1Is the
The exhaust gas stored in the first liquid reservoir 209 and desulfurized is, for example,
Dividing plate 214 for dividing the first liquid reservoir 209 and the second liquid reservoir 210
Passing through the upper space toward the second absorption tower 202
Ku.
【００１３】この第１吸収塔２０１において、例えば約
１，０００ｐｐｍのＳＯｘを含む燃焼排ガス２００中の
ＳＯｘはスラリＳ1 中の炭酸カルシウムによって吸収除
去され、ＳＯｘ濃度が数十ｐｐｍ程度まで脱硫される。In the first absorption tower 201, SOx in the combustion exhaust gas 200 containing SOx of about 1,000 ppm, for example, is absorbed and removed by the calcium carbonate in the slurry S 1 , and the SOx concentration is desulfurized to about several tens of ppm. ..
【００１４】第２吸収塔２０２に送られた脱硫排ガスは
第２吸収塔２０２内で、ポンプＰ2、第２循環ライン２
０６を介して第２ノズル２０４より噴霧される第２液溜
２１０の吸収剤であるスラリＳ2 （１％以上の炭酸カル
シウムを含むスラリ）と接触（例えば向流接触）させら
れ、必要に応じて設けられた第２充填層２０８を通過
し、この間にスラリＳ2 中の炭酸カルシウムによってさ
らに脱硫され、第１吸収塔２０１でＳＯｘ濃度数十ｐｐ
ｍ程度まで脱硫された排ガスはＳＯｘ濃度１０ｐｐｍ以
下となり、最終的に脱硫排ガス２５０となって第２吸収
塔２０２に排出される。この第２吸収塔は能力的には処
理ガス中のＳＯｘ濃度を１ｐｐｍまでも脱硫することも
可能なものである。The desulfurized exhaust gas sent to the second absorption tower 202 is pumped by the pump P 2 and the second circulation line 2 in the second absorption tower 202.
It is brought into contact (for example, countercurrent contact) with slurry S 2 (slurry containing 1% or more of calcium carbonate) which is the absorbent of the second liquid reservoir 210 sprayed from the second nozzle 204 via 06, and if necessary. It passes through the second packed bed 208 provided in the first absorption tower 201 and is further desulfurized by the calcium carbonate in the slurry S 2 , and the SOx concentration is several tens pp in the first absorption tower 201.
The exhaust gas desulfurized to about m has a SOx concentration of 10 ppm or less, and finally becomes desulfurized exhaust gas 250 and is discharged to the second absorption tower 202. This second absorption tower is capable of desulfurizing the SOx concentration in the treated gas up to 1 ppm.
【００１５】第２吸収塔２０２を循環する吸収剤である
スラリＳ2 は、吸収するＳＯｘの絶対量は少ないので、
第２液溜２１０のスラリＳ2 中の炭酸カルシウム濃度の
減少は小さいが、次第に炭酸カルシウムの濃度は減少す
るので、第２液溜２１０にその減少に見合う炭酸カルシ
ウムを補給する。従って第２液溜２１０のスラリＳ2の
炭酸カルシウムの濃度は常に第１液溜２０９のスラリＳ
1 のそれより大であるので、該スラリＳ2 を、例えば移
送ライン２１１、コントロールバルブ２１２により第１
液溜２０９のスラリＳ1 のｐＨ上昇用に使用し、第１吸
収塔２０１のスラリＳ1 の脱硫能力を維持するようにす
る。Since the slurry S 2 which is the absorbent circulating in the second absorption tower 202 absorbs a small amount of SOx,
Although the decrease in the calcium carbonate concentration in the slurry S 2 of the second liquid reservoir 210 is small, the concentration of calcium carbonate gradually decreases, so that the second liquid reservoir 210 is supplemented with calcium carbonate corresponding to the decrease. Therefore, the concentration of calcium carbonate in the slurry S 2 of the second liquid reservoir 210 is always the slurry S 2 of the first liquid reservoir 209.
Since it is larger than that of 1, the slurry S 2 is supplied to the first by a transfer line 211, a control valve 212, for example.
It is used to raise the pH of the slurry S 1 in the liquid reservoir 209 so as to maintain the desulfurization ability of the slurry S 1 of the first absorption tower 201.
【００１６】なお、第１吸収塔２０１と第２吸収塔２０
２の排ガスの通路（図２の分割板２１４の上部空間）に
はデミスタ２１３を設けて排ガスに帯同する飛散ミスト
が第１吸収塔２０１より第２吸収塔２０２に流入するの
を防ぐようにすることが好ましい。The first absorption tower 201 and the second absorption tower 20
A demister 213 is provided in the second exhaust gas passage (upper space of the dividing plate 214 in FIG. 2) to prevent scattered mist accompanying the exhaust gas from flowing into the second absorption tower 202 from the first absorption tower 201. Preferably.
【００１７】前記高性能脱硫装置において、脱硫レベル
を上げるほど脱硫装置に必要な消費電力は上昇する。一
方、脱硫レベルを下げると、後述のように脱硫工程で残
存するＳＯｘが脱ＣＯ2 工程においてアルカノールアミ
ンと反応し、高価なアルカノールアミンのロスが多くな
り、また結果的にスラッジの発生量も多くなるので好ま
しくない。従って高性能脱硫工程における脱硫レベルと
して、処理ガス中のＳＯｘ濃度を５〜１０ｐｐｍの範囲
に設定することが好ましい。In the high performance desulfurizer, the power consumption required for the desulfurizer increases as the desulfurization level increases. On the other hand, when the desulfurization level is lowered, the SOx remaining in the desulfurization process reacts with the alkanolamine in the CO 2 removal process as described later, resulting in a large loss of expensive alkanolamine and, as a result, a large amount of sludge generation. Therefore, it is not preferable. Therefore, as the desulfurization level in the high-performance desulfurization step, it is preferable to set the SOx concentration in the processing gas within the range of 5 to 10 ppm.
【００１８】本発明においては、燃焼排ガスを脱硫工程
により脱硫処理した後、脱ＣＯ2 工程によりアルカノー
ルアミン水溶液と接触させてＣＯ2 を除去する。この場
合に、前記高性能脱硫装置を用いて脱硫工程で残存する
ＳＯｘ濃度を５〜１０ｐｐｍの範囲にすると、前記のよ
うに脱ＣＯ2 処理ガス中のＳＯｘ濃度を効率よく１ｐｐ
ｍ以下に抑えることができる。In the present invention, after desulfurized by a flue gas desulfurization process, it is contacted with an aqueous alkanolamine solution for removal of CO 2 by removing CO 2 step. In this case, if the SOx concentration remaining in the desulfurization step is set within the range of 5 to 10 ppm using the high-performance desulfurization apparatus, the SOx concentration in the CO 2 removal processing gas can be efficiently adjusted to 1 pp as described above.
It can be suppressed to m or less.
【００１９】ここで、ＣＯ2 を吸収するアルカノールア
ミン水溶液としてはモノエタノールアミン、ジエタノー
ルアミン、トリエタノールアミン、メチルジエタノール
アミン、ジイソプロパノールアミン、ジグリコールアミ
ンなどの水溶液、あるいはこれらの混合水溶液を挙げる
ことができるが、通常モノエタノールアミン（ＭＥＡ）
水溶液が好んで用いられる。Examples of the alkanolamine aqueous solution that absorbs CO 2 include monoethanolamine, diethanolamine, triethanolamine, methyldiethanolamine, diisopropanolamine, diglycolamine, and the like, or a mixed solution thereof. But usually monoethanolamine (MEA)
Aqueous solutions are preferred.
【００２０】燃焼排ガス中に含まれるＣＯ2 をアルカノ
ールアミン水溶液、特にはＭＥＡ水溶液を用いて除去す
るプロセスは特に限定されないが、その一例について図
３によって説明する。図３では主要設備のみ示し、付属
設備は省略した。The process for removing CO 2 contained in the combustion exhaust gas using an alkanolamine aqueous solution, particularly an MEA aqueous solution, is not particularly limited, but an example thereof will be described with reference to FIG. In FIG. 3, only the main equipment is shown and the auxiliary equipment is omitted.
【００２１】図３において、３０１は脱ＣＯ2 塔、３０
２は下部充填部、３０３は上部充填部またはトレイ、３
０４は脱ＣＯ2 塔燃焼排ガス供給口、３０５は脱ＣＯ2
燃焼排ガス排出口、３０６はＭＥＡ水溶液供給口、３０
７は第１ノズル、３０８は第２ノズル、３０９は必要に
応じて設けられる燃焼排ガス冷却器、３１０はノズル、
３１１は充填部、３１２は加湿冷却水循環ポンプ、３１
３は補給水供給ライン、３１４はＣＯ2 吸収ＭＥＡ水溶
液排出ポンプ、３１５は熱交換器、３１６はＭＥＡ水溶
液再生塔（以下、「再生塔」と略称）、３１７は第１ノ
ズル、３１８は下部充填部、３１９は再生加熱器（リボ
イラ）、３２０は上部充填部、３２１は還流水ポンプ、
３２２はＣＯ2 分離器、３２３は回収ＣＯ2 排出ライ
ン、３２４は再生塔還流冷却器、３２５は第２ノズル、
３２６は再生塔還流水供給ライン、３２７は必要に応じ
て設けられる冷却器、３２８は燃焼排ガス供給ブロア、
３２９はリクレーマ（蓄積熱安定塩除去装置）、Ｇは図
１と同様にスラッジ移送設備である。In FIG. 3, 301 is a CO 2 removal tower, 30
2 is a lower filling section, 303 is an upper filling section or tray, 3
Reference numeral 04 denotes a CO 2 tower combustion exhaust gas supply port, and 305 denotes CO 2 removal
Combustion exhaust gas discharge port, 306 is MEA aqueous solution supply port, 30
7 is a first nozzle, 308 is a second nozzle, 309 is a combustion exhaust gas cooler provided as necessary, 310 is a nozzle,
311 is a filling part, 312 is a humidification cooling water circulation pump, 31
3 is a makeup water supply line, 314 is a CO 2 absorption MEA aqueous solution discharge pump, 315 is a heat exchanger, 316 is a MEA aqueous solution regeneration tower (hereinafter referred to as “regeneration tower”), 317 is a first nozzle, 318 is a lower filling Part, 319 is a regenerative heater (reboiler), 320 is an upper filling part, 321 is a reflux water pump,
322 is a CO 2 separator, 323 is a recovered CO 2 discharge line, 324 is a regenerator reflux condenser, 325 is a second nozzle,
326 is a regeneration tower reflux water supply line, 327 is a cooler provided as needed, 328 is a combustion exhaust gas supply blower,
329 is a reclaimer (accumulated heat stable salt removing device), and G is a sludge transfer facility as in FIG.
【００２２】図３において、脱硫工程を経た燃焼排ガス
は燃焼排ガス供給ブロア３２８により燃焼排ガス冷却器
３０９に押込められ、ノズル３１０からの加湿冷却水と
充填部３１１で接触して加湿冷却され、脱ＣＯ2 塔燃焼
排ガス供給口３０４を通って脱ＣＯ2 塔３０１へ導かれ
る。燃焼排ガスと接触した加湿冷却水は燃焼排ガス冷却
器３０９の下部に溜り、ポンプ３１２によりノズル３１
０へ循環使用される。加湿冷却水は燃焼排ガスを加湿冷
却させることにより徐々に失われるので、補給水供給ラ
イン３１３により補充される。In FIG. 3, the combustion exhaust gas that has undergone the desulfurization process is pushed into the combustion exhaust gas cooler 309 by the combustion exhaust gas supply blower 328, and is contacted with the humidified cooling water from the nozzle 310 at the filling portion 311 to be humidified and cooled, and then degassed. It is guided to the CO 2 removal tower 301 through the CO 2 tower combustion exhaust gas supply port 304. The humidified cooling water that has come into contact with the combustion exhaust gas collects in the lower part of the combustion exhaust gas cooler 309, and is pumped by the nozzle 312.
It is recycled to 0. Since the humidified cooling water is gradually lost by humidifying and cooling the combustion exhaust gas, it is replenished by the makeup water supply line 313.
【００２３】脱ＣＯ2 塔３０１に押し込められた燃焼排
ガスは第１ノズル３０７から供給される一定濃度のＭＥ
Ａ水溶液と下部充填部３０２で向流接触させられ、燃焼
排ガス中のＣＯ2 はＭＥＡ水溶液により吸収除去され、
脱ＣＯ2 燃焼排ガスは上部充填部３０３へと向う。脱Ｃ
Ｏ2 塔３０１に供給されるＭＥＡ水溶液はＣＯ2 を吸収
し、その吸収による反応熱のため、ＭＥＡ水溶液供給口
３０６における温度よりも高温となり、ＣＯ2 吸収ＭＥ
Ａ水溶液排出ポンプ３１４により熱交換器３１５に送ら
れ、加熱され、再生塔３１６へ導かれる。再生されたＭ
ＥＡ水溶液の温度調節は熱交換器３１５あるいは必要に
応じて熱交換器３１５とＭＥＡ水溶液供給口３０６の間
に設けられる冷却器３２７により行うことができる。The combustion exhaust gas pushed into the CO 2 removal tower 301 is supplied from the first nozzle 307 with a constant concentration of ME.
The aqueous solution A is brought into countercurrent contact with the lower filling section 302, CO 2 in the combustion exhaust gas is absorbed and removed by the aqueous MEA solution,
The de-CO 2 combustion exhaust gas goes to the upper filling section 303. De-C
The MEA aqueous solution supplied to the O 2 tower 301 absorbs CO 2, and due to the reaction heat due to the absorption, the temperature becomes higher than the temperature at the MEA aqueous solution supply port 306, and the CO 2 absorption ME
It is sent to the heat exchanger 315 by the A solution discharge pump 314, heated, and guided to the regeneration tower 316. Played M
The temperature of the EA aqueous solution can be adjusted by the heat exchanger 315 or, if necessary, the cooler 327 provided between the heat exchanger 315 and the MEA aqueous solution supply port 306.
【００２４】再生塔３１６では、再生加熱器（リボイ
ラ）３１９による加熱でＭＥＡ水溶液が再生され、熱交
換器３１５により冷却され脱ＣＯ2 塔３０１へ戻され
る。再生塔３１６の上部において、ＭＥＡ水溶液から分
離されたＣＯ2 は第２ノズル３２５より供給される還流
水と接触し、再生塔還流冷却器３２４により冷却され、
ＣＯ2 分離器３２２にてＣＯ2 に同伴した水蒸気が凝縮
した還流水と分離され、回収ＣＯ2 排出ライン３２３よ
りＣＯ2 回収工程へ導かれる。還流水の一部は還流水ポ
ンプ３２１で再生塔３１６へ還流され、他の一部は再生
塔還流水供給ライン３２６を経て脱ＣＯ2 塔３０１の上
部の第２ノズル３０８と供給される。In the regeneration tower 316, the MEA aqueous solution is regenerated by heating by the regeneration heater (reboiler) 319, cooled by the heat exchanger 315 and returned to the CO 2 removal tower 301. In the upper part of the regeneration tower 316, the CO 2 separated from the MEA aqueous solution comes into contact with the reflux water supplied from the second nozzle 325, and is cooled by the regeneration tower reflux condenser 324.
In the CO 2 separator 322, the steam entrained in CO 2 is separated from the condensed reflux water, and is introduced from the recovered CO 2 discharge line 323 to the CO 2 recovery process. A part of the reflux water is refluxed to the regeneration tower 316 by the reflux water pump 321, and another part is supplied to the second nozzle 308 above the CO 2 removal tower 301 via the regeneration tower reflux water supply line 326.
【００２５】本発明においては、脱硫工程で処理された
燃焼排ガスは脱ＣＯ2 工程で処理されることによりＣＯ
2 が除去されるが、同時に残存するＳＯｘはほぼ完全に
除去される。これは、前記のように脱ＣＯ2 工程で使用
されるＭＥＡ等のアルカノールアミンと残存ＳＯｘが反
応するためであり、この反応によって再生等３１６にお
いて通常ＭＥＡが再生され得ない程度に安定な塩が生じ
る。従って、安定塩は徐々に脱ＣＯ2 工程系内に蓄積さ
れるので、たとえば定期的に図３のリクレーマ（蓄積ス
ラッジ除去装置）３２９を稼働させ、再生塔３１６の塔
底液を処理する。その際、スラッジ化剤として炭酸ナト
リウムのような塩類を使用してもよい。塔底液はリクレ
ーマ３２９において、リボイラ３１９による加熱温度
（通常１２０℃前後）よりも高い温度（例えば１３５℃
前後）で加熱されるので、ＭＥＡや水分は再生塔３１６
にもどされるが、安定塩はスラッジとなってリクレーマ
３２９に濃縮される。In the present invention, the combustion exhaust gas treated in the desulfurization process is treated in the CO 2 removal process to produce CO
2 is removed, but at the same time, the remaining SOx is almost completely removed. This is because the residual SOx reacts with the alkanolamine such as MEA used in the CO 2 removal step as described above, and this reaction produces a stable salt to the extent that the MEA is not usually regenerated in regeneration 316. Occurs. Therefore, the stable salt is gradually accumulated in the CO 2 removal process system, and thus the reclaimer (accumulated sludge removing device) 329 of FIG. 3 is periodically operated to treat the bottom liquid of the regeneration column 316. At that time, salts such as sodium carbonate may be used as a sludge agent. In the reclaimer 329, the bottom liquid is higher than the heating temperature (usually around 120 ° C) by the reboiler 319 (for example, 135 ° C).
Since it is heated in the front and back), the MEA and water are regenerated in the regeneration tower 316.
Although it is returned, the stable salt becomes sludge and is concentrated in the reclaimer 329.
【００２６】本発明の特徴は、ここで発生するスラッジ
を、脱硫や脱ＣＯ2 処理をすべき燃焼排ガスを発生させ
る燃焼装置、すなわち図１ではボイラＡにて燃焼させる
ことにある。これにより、スラッジに含まれる安定塩等
は燃焼排ガスの一部となって、再び図１の脱硝、集塵、
脱硫、脱ＣＯ2 の各工程を経て処理されることになる。
従って、本発明により単に焼却すれば副次的に汚染の原
因となるスラッジを完全に閉鎖工程の中で処理できるこ
とになる。The feature of the present invention resides in that the sludge generated here is burned in a combustion device for generating combustion exhaust gas to be subjected to desulfurization and CO 2 removal treatment, that is, a boiler A in FIG. As a result, the stable salt contained in the sludge becomes a part of the combustion exhaust gas, and the denitration, dust collection, and
It is processed through each step of desulfurization and CO 2 removal.
Therefore, according to the present invention, sludge, which causes secondary pollution, can be completely treated in a closed process by simply incinerating.
【００２７】スラッジ移送設備Ｇとしては特に限定され
ず、どのような手段でもよい。例えばスラッジをポンプ
にて昇圧して送るとか、あるいは液体燃料と混合して流
動化させパイプで移送させる方法などが挙げられる。ボ
イラでの燃焼方法としてはバーナー部分に上記流動化し
たスラッジを吹き付ける方法等が例示される。またスラ
ッジの燃焼を助けるため各種助燃剤を用いてもよい。The sludge transfer facility G is not particularly limited, and any means may be used. For example, there is a method in which the pressure of sludge is increased by a pump and then sent, or a method in which the sludge is mixed with a liquid fuel, fluidized, and transferred by a pipe. Examples of the combustion method in the boiler include a method of spraying the fluidized sludge on the burner portion. Further, various combustion improvers may be used to assist the combustion of sludge.
【００２８】前記のように、安定塩となってスラッジを
形成するアルカノールアミン分は回収されないので、脱
ＣＯ2 工程においてはそのロス分を補給しなければなら
ない。このような理由から、脱ＣＯ2 工程にて処理され
る燃焼排ガス中のＳＯｘ濃度はできるだけ抑えることが
好ましい。しかし、前述のように脱ＣＯ2 工程の前に設
けられる脱硫工程で脱硫レベルを上げることは、消費電
力の増大につながる。従って本発明においては、脱硫工
程による処理ガス中のＳＯｘ濃度を１０〜５ｐｐｍの範
囲内に設定することが好ましい。これにより、脱硫工程
における消費電力の上昇を避けると共に、脱ＣＯ2 工程
における高価なアルカノールアミンのロスも最小限に抑
え、しかも脱ＣＯ2 工程を経た処理ガス中のＳＯｘは１
ｐｐｍ以下、すなわちほぼ完全にＳＯｘの除去が可能と
なる。As described above, since the alkanolamine component which forms a stable salt and forms sludge is not recovered, the loss component must be supplemented in the CO 2 removal step. For these reasons, it is preferable to suppress the SOx concentration in the combustion exhaust gas treated in the CO 2 removal step as much as possible. However, increasing the desulfurization level in the desulfurization process provided before the CO 2 removal process as described above leads to an increase in power consumption. Therefore, in the present invention, it is preferable to set the SOx concentration in the processing gas in the desulfurization step within the range of 10 to 5 ppm. This prevents an increase in power consumption in the desulfurization process, minimizes the loss of expensive alkanolamine in the CO 2 removal process, and reduces SOx in the process gas after the CO 2 removal process to 1%.
It is possible to remove SOx below ppm, that is, almost completely.
【００２９】[0029]
【実施例】以下、実施例により本発明を具体的に説明す
る。EXAMPLES The present invention will be specifically described below with reference to examples.
【００３０】（実施例Ａ）図２の脱硫装置を用い、下記
の処理条件でＳＯ2 濃度１，０００ｐｐｍの燃焼排ガス
を処理した。その際のスラリ循環量を変えて動力（電
力）と処理ガス中のＳＯ2 濃度の関係は表１のとおりで
あった。(Example A) Using the desulfurization apparatus shown in FIG. 2, combustion exhaust gas having an SO 2 concentration of 1,000 ppm was treated under the following treatment conditions. Table 1 shows the relationship between the power (electric power) and the SO 2 concentration in the treated gas by changing the slurry circulation amount at that time.
【００３１】（１）処理条件 Ｌ／Ｇ（Ｌ：スラリ液量、Ｇ：排ガス量）：２５．６ 第１吸収塔の高さ：１９ｍ 第２吸収塔の高さ：１７ｍ 第１吸収塔のスラリ固形成分中の炭酸カルシウムの割
合：１．０重量％以下 第２吸収塔のスラリ固形成分中の炭酸カルシウムの割
合：１．０重量％以上 第１吸収塔における脱硫率：９８％ 第２吸収塔における脱硫率：９５％ 処理燃焼排ガス量：１，０００，０００Ｎｍ3 ／ｈ 処理燃焼排ガス温度：５０℃ スラリ温度：５０℃(1) Treatment conditions L / G (L: amount of slurry liquid, G: amount of exhaust gas): 25.6 Height of first absorption tower: 19 m Height of second absorption tower: 17 m Proportion of calcium carbonate in the slurry solid component: 1.0 wt% or less Proportion of calcium carbonate in the slurry solid component of the second absorption tower: 1.0 wt% or more Desulfurization rate in the first absorption tower: 98% Second absorption Desulfurization rate in the tower: 95% Treated flue gas amount: 1,000,000 Nm 3 / h Treated flue gas temperature: 50 ° C Slurry temperature: 50 ° C
【００３２】（２）処理結果(2) Processing result
【表１】 [Table 1]
【００３３】次に図２脱硫装置と、図３の脱ＣＯ2 装置
を組み合わせ、上記各脱硫レベルの燃焼排ガスを脱ＣＯ
2 処理した。その結果、脱ＣＯ2 処理ガス中に含まれる
ＳＯ 2 濃度はいずれも検出限界以下、すなわち１ｐｐｍ
以下であった。この状態で処理工程の稼働を続けたとこ
ろ、リクレーマから固形分として約１５０ｋｇ／ｈのス
ラッジが発生する。このスラッジの中には約１０ｋｇ／
ｈの硫黄分を含んでおり、これをボイラＡにおいて燃焼
させＳＯｘに転化させる。Next, the desulfurization apparatus shown in FIG. 2 and the CO removal shown in FIG.2apparatus
Combustion exhaust gas of each of the above desulfurization levels is removed by CO
2Processed. As a result, de-CO2Contained in process gas
SO 2All concentrations are below the detection limit, ie 1ppm
It was below. In this state, the processing process continued to operate.
The solid content of the reclaimer is about 150 kg / h.
Ludge occurs. About 10 kg / in this sludge
It contains the sulfur content of h, and burns it in boiler A.
And convert to SOx.
【００３４】（実施例Ｂ）図３の小型モデル実験装置と
して濡れ壁型吸収装置を用い、ＣＯ2 、酸素（Ｏ 2 ）、
ＳＯ2 、ＮＯ2 の濃度を調製したガスとＭＥＡ水溶液の
接触吸収実験を行った。各試験に共通の条件は以下の通
りである。なお、供給ガス中のＣＯ2 とＯ 2 濃度は平均
的なボイラ燃焼排ガス濃度に設定した。(Embodiment B) With the small model experimental apparatus of FIG.
Then, using a wet wall type absorber, CO2, Oxygen (O 2),
SO2, NO2Of the concentration of gas and MEA solution
A contact absorption experiment was conducted. The conditions common to each test are as follows.
It is Ri. In addition, CO in the supply gas2And O 2Average concentration
It was set to the typical boiler combustion exhaust gas concentration.
【００３５】（１）共通条件 ＣＯ2 吸収塔方式：濡れ壁吸収塔 同高さ：７５００ｍｍ 供給ガス（Ｇ）中のＣＯ2 濃度：９ｖｏｌ％ 供給ガス中のＯ2 濃度：９ｖｏｌ％ 供給ガス温度：６０℃ 供給ガス流量：２．０ｍ3 Ｎ／ｈ・ｄｒｙ ＭＥＡ水溶液（Ｌ）のＭＥＡ濃度：３０重量％ ＭＥＡ水溶液流量：４．０リットル／ｈ ＭＥＡ水溶液温度：６０℃ Ｌ／Ｇ比：２．０リットル／ｍ3 Ｎ ガス空塔速度：３．１ｍＮ／ｓ(1) Common conditions CO 2 absorption tower system: Wetting wall absorption tower Same height: 7500 mm CO 2 concentration in supply gas (G): 9 vol% O 2 concentration in supply gas: 9 vol% Supply gas temperature: 60 ° C. Supply gas flow rate: 2.0 m 3 N / h · dry MEA aqueous solution (L) MEA concentration: 30 wt% MEA aqueous solution flow rate: 4.0 liters / h MEA aqueous solution temperature: 60 ° C. L / G ratio: 2. 0 L / m 3 N superficial velocity of gas: 3.1 mN / s
【００３６】（２）実験結果(2) Experimental result
【表２】 [Table 2]
【００３７】ＣＯ2 の吸収率はいずれも９５％であっ
た。上記表２から分かるように、ＳＯ 2 はＭＥＡ水溶液
に吸収されて、いずれも検出限界以下、すなわち１ｐｐ
ｍ以下に抑えることができた。また、ＮＯ2 はいずれも
ほぼ２０％の吸収率であった。また、ＣＯ2 の吸収率は
上記の通り、ＳＯ2 やＮＯ2 の濃度に影響されないこと
も分かった。この実験終了後に、ＭＥＡ水溶液を蒸発乾
固させたところ、安定塩が得られた。これをバーナで燃
焼試験をしたところ、支障なく燃焼した。CO2The absorption rate of each is 95%
It was As can be seen from Table 2 above, SO 2Is an MEA aqueous solution
Absorbed below the detection limit, that is, 1pp
It could be suppressed to m or less. Also, NO2Are both
The absorption rate was almost 20%. Also, CO2The absorption rate of
As above, SO2And NO2Not be affected by the concentration of
I also understood. After this experiment was completed, the MEA aqueous solution was evaporated and dried.
Upon solidification, a stable salt was obtained. Burn this with a burner
As a result of a baking test, it burned without any trouble.
【００３８】[0038]
【発明の効果】以上詳細に述べたごとく、本発明の方法
により、燃焼排ガスからＣＯ2 を除去すると共に、副次
的にもＳＯｘを発生させることなくほぼ完全にＳＯｘを
除去することが可能となった。As described in detail above, according to the method of the present invention, it is possible to remove CO 2 from the combustion exhaust gas and to almost completely remove SOx without secondary generation of SOx. became.
【図１】本発明で採用する工程の説明図。FIG. 1 is an explanatory diagram of a process adopted in the present invention.
【図２】本発明で採用することが好ましい高性能脱硫工
程の一態様の説明図。FIG. 2 is an explanatory diagram of one embodiment of a high-performance desulfurization process that is preferably adopted in the present invention.
【図３】本発明で採用する脱ＣＯ2 工程の一態様の説明
図。FIG. 3 is an explanatory diagram of one embodiment of a CO 2 removal step adopted in the present invention.
───────────────────────────────────────────────────── フロントページの続き (72)発明者 堀田 善次 大阪府大阪市北区中之島３丁目３番22号 関西電力株式会社内 (72)発明者 小林 賢治 大阪府大阪市北区中之島３丁目３番22号 関西電力株式会社内 (72)発明者 吉田 邦彦 大阪府大阪市北区中之島３丁目３番22号 関西電力株式会社内 (72)発明者 下條 繁 大阪府大阪市北区中之島３丁目３番22号 関西電力株式会社内 (72)発明者 北村 耕一 大阪府大阪市北区中之島３丁目３番22号 関西電力株式会社内 (72)発明者 川崎 雅己 大阪府大阪市北区中之島３丁目３番22号 関西電力株式会社内 (72)発明者 瀬戸 徹 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 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 本田 充康 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 菱重工業株式会社内 ─────────────────────────────────────────────────── ─── Continuation of the front page (72) Inventor Zenji Hotta 3-3-22 Nakanoshima, Kita-ku, Osaka-shi, Osaka Kansai Electric Power Co., Inc. (72) Kenji Kobayashi 3-chome Nakanoshima, Kita-ku, Osaka-shi, Osaka No. 22 in Kansai Electric Power Co., Inc. (72) Inventor Kunihiko Yoshida 3-3 Nakanoshima, Kita-ku, Osaka City, Osaka Prefecture No. 22 Inside Kansai Electric Power Co., Inc. (72) Shigeru Shimojo 3-3 Nakanoshima, Kita-ku, Osaka City, Osaka Prefecture No.22 in Kansai Electric Power Co., Inc. (72) Inventor Koichi Kitamura 3-3 Nakanoshima, Kita-ku, Osaka City, Osaka Prefecture No. 22 Inside Kansai Electric Power Co., Inc. (72) Masami Kawasaki 3-chome, Nakanoshima, Kita-ku, Osaka City, Osaka Prefecture No.22 in Kansai Electric Power Co., Inc. (72) Inventor Toru Seto 4-6-22 Kannon-shinmachi, Nishi-ku, Hiroshima-shi, Hiroshima Prefecture Mitsubishi Heavy Industries Ltd. Hiroshima Research Institute (72) Inventor Mitsuoka Ming 4-6-22 Kannon Shinmachi, Nishi-ku, Hiroshima-shi, Hiroshima Prefecture Mitsubishi Heavy Industries, Ltd. Hiroshima Research Institute (72) Inventor Mitsuyasu Honda 6-22 Kannon-shinmachi, Nishi-ku, Hiroshima City, Hiroshima Mitsubishi Heavy Industries Ltd. 72) Inventor Masaki Iijima 2-5-1, Marunouchi, Chiyoda-ku, Tokyo Sanryo Heavy Industries Co., Ltd.
Claims (2)
排ガスを脱硫処理する工程および前記脱硫処理されたガ
スをアルカノールアミン水溶液と接触させてＣＯ2 を除
去する脱ＣＯ2 工程により燃焼排ガス中のＣＯ2 とＳＯ
ｘを除去する方法において、脱ＣＯ2 工程から発生する
リクレーマよりのスラッジを前記燃焼装置で燃焼させる
ことを特徴とする燃焼排ガス中のＣＯ2 とＳＯｘを除去
する方法。1. CO in flue gas by a step of desulfurizing combustion exhaust gas containing SOx generated from a combustion device and a CO 2 removing step of contacting the desulfurized gas with an aqueous alkanolamine solution to remove CO 2. 2 and SO
In the method of removing x, a method of removing CO 2 and SOx in the combustion exhaust gas, which comprises burning sludge from the reclaimer generated from the CO 2 removal step in the combustion device.
のＳＯｘ濃度が５〜１０ｐｐｍの範囲内になるように脱
硫処理したのち、前記脱硫処理ガスを脱ＣＯ 2 工程によ
りＣＯ2 を除去すると共に脱ＣＯ2 処理ガス中のＳＯｘ
の濃度が１ｐｐｍ以下となるようにＳＯｘを除去するこ
とを特徴とする請求項１記載の燃焼排ガス中のＣＯ2 と
ＳＯｘを除去する方法。2. In the desulfurization treatment gas according to the desulfurization treatment step
So that the SOx concentration is within the range of 5-10ppm.
After the sulfur treatment, the desulfurization treatment gas is subjected to CO removal. 2By process
Ri CO2To remove CO2SOx in process gas
SOx must be removed so that the concentration of
CO in combustion exhaust gas according to claim 1, characterized in that2When
A method of removing SOx.
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| JP04524592A JP3504674B2 (en) | 1992-03-03 | 1992-03-03 | Method for removing carbon dioxide and sulfur oxides from flue gas |
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|---|---|---|---|
| JP04524592A JP3504674B2 (en) | 1992-03-03 | 1992-03-03 | Method for removing carbon dioxide and sulfur oxides from flue gas |
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| JP3504674B2 JP3504674B2 (en) | 2004-03-08 |
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| JP04524592A Expired - Lifetime JP3504674B2 (en) | 1992-03-03 | 1992-03-03 | Method for removing carbon dioxide and sulfur oxides from flue gas |
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