201247995 六、發明說明： 【發明所屬之技術領域】 本發明大體係關於熱電廠。更特定言之，本發明係關於 整合過程控制方案以便利用發電廠蒸汽進行二氧化碳擷 取、從而使廢熱降至最低的方法及系統。 本申請案根據35 U.S.C 119(e)主張2011年3月31日申請之 名為 A SYSTEM AND METHOD FOR CONTROLLING WASTE HEAT FOR C02 CAPTURE之臨時專利申請案第 61/469,915號的權利，該案揭示内容以全文引用的方式併 入本文中。 相關申請案之交叉引用 本申請案之相關申請案為2011年3月31曰與本申請案同 時申請、名為「A SYSTEM AND METHOD FOR CONTROLLING WASTE HEAT FOR C02 CAPTURE」且已讓渡於本發明之 受讓人的美國專利申請案第61/469,919號（代理人案號 W09/056-0(27849-0014)) ’且該案以全文引用的方式併入 本文中。 【先前技術】 化石燃料及天然氣發電站習知使用蒸汽渦輪機及其他機 器將熱轉化為電。該等燃料燃燒產生廢氣流，包括含有二 氧化碳C02、氮氧化物NOx及硫氧化物SOx的酸氣。已做出 努力減少該等發電站之酸氣排放，且尤其減少包括C02之 溫室氣體排放。因而，已將C02擷取系統整合於該等發電 站内。在此方面已取得許多進步，從而將化石燃料燃燒期 163487.doc 201247995 間所產生之eh部分地至完全地與燃燒氣體分離❶近來， 已關注使用胺水溶液自燃燒氣流移除酸氣污染物之水溶液 吸收及汽提方法。 氣體吸收為將氣體混合物之可溶成分溶於液體中之方 法。氣體/液體接觸可為逆流或並流接觸，其中逆流接觸 最常採用。汽提本質上為逆向吸收，因為其涉及揮發性成 分自液體混合物轉移至氣體。在—典型二氧化碳移除方法 中，使用吸收自燃燒氣體移除二氧化碳，且接著使用汽提 再生溶劑及擷取溶劑中所含之二氧化碳。二氧化碳一旦自 燃燒氣體及其他氣體移除，其即可經擷取及壓縮以用於包 括螯合、曱醇生產及三次石油回收之許多應用。 為再生吸收溶液，自吸收塔底部抽出之富溶劑引入汽提 蝽之上半部中，且該富溶劑在壓力下在其沸點或接近其沸 點之高溫下維持。維持該高溫所需之熱由汽提塔中所含之 吸收溶液再沸供給’其需要能量且因此提高總操作成本。 因此’需要向再沸器提供節省成本且操作高效之能源以 再生所負載之胺水溶液流。 【發明内容】 本發明之一目的為提供向與蒸汽發電系統整合之酸氣吸 收/汽提過程有效提供熱的系統及方法。 本發明之另一目的為使發電廠總效能最佳化此係藉由 使用來自不同渦輪機級及水及/或蒸汽循環位置之蒸汽分 支（抽出點）之特殊配置向酸氣擷取系統提供能量。 本發明之另-目的為提供來自不同滿輪機級及水及/或 163487.doc 201247995 洛汽循環位置之蒸汽分支（抽出點）之特殊配置以向酸氣擷 取系統提供能量，該酸氣擷取系統可設計為新系統或根據 現有發電系統設計加以改進。 本發明之另一目的為提供整合蒸汽發電負載與能量產生 供酸氣擷取的過程控制方案。 因此，視供酸軋掏取之已知技術的操作參數及設計參數 而定，本發明之一目的可在於降低能量耗用。 此外，本發明之一目的可在於用該技術吸收酸氣而減少 化學品排放之環境、健康及/或經濟改善。 在一態樣中，所揭示之工廠包括：產生蒸汽之鍋爐單 元、包括至少一個接收來自該鍋爐單元之蒸汽之發電渦輪 的發電單元、包含兩個或兩個以上再生塔之氣體回收單 兀、針對兩個或兩個以上再生塔之次蒸汽源，及經組態以 調節蒸汽至兩個或兩個以上再生塔之流量的控制器。該控 制器包括基於工廠負載參數確定蒸汽自蒸汽源至兩個或兩 個以上再生塔之各再生塔之流量的控制策略。 在另一態樣中，揭示向氣體回收單元提供蒸汽之方法， 其包括基於發電單元之負載參數控制蒸汽至氣體回收單元 之兩個或兩個以上再生塔的流量。 【實施方式】 現參看諸圖，其為例示性實施例，且其中相同元件編號 相同。 以下參考圖式描述根據本發明使用發電蒸汽向酸氣回收 提供能量之系統及方法的特定實施例。 163487.doc 201247995 圖1根據本發明之一實施例說明工廠1〇〇的示意性簡化方 法圖。在-贲施例中，&系統100可為熱電廠。在另一實 施例中，工廠1〇〇可為包括產生含有二氧化碳之廢氣之燃 燒裝置及至少一個蒸汽單元的工廠或裝置。該蒸汽單元可 為蒸汽渦輪發電單元。 如圖1所示，工廠100包括主蒸汽源11〇、發電單元119及 氣體回收單元130。在該例示性實施例中，主蒸汽源1為 蒸汽鍋爐單元。蒸汽鍋爐單元丨10可包括一或多個利用化 石燃料產生蒸汽之蒸汽鍋爐^該燃料可為煤、泥煤、生物 質、合成氣/燃料、天然氣或其他碳燃料源，當燃燒時， 其產生含有諸如酸氣之氣體污染物的廢氣。 發電單元119包括主蒸汽消耗裝置120及發電單元125。 在該例示性實施例中，主蒸汽消耗裝置12〇為一或多個蒸 汽渦輪機。一或多個蒸汽渦輪機12〇耦接至發電單元i 25以 向發電機125提供機械能而產生電力125A。該電力可提供 至電網（未圖示）。在該例示性實施例中，一或多個蒸汽满 輪機120包括高壓（HP)渦輪機121、中壓（ip)渦輪機122及低 壓（LP)渦輪機123。在另一實施例中，一或多個蒸汽滿輪 機120可包括許多具有相似或不同操作壓力之渦輪機的組 合0 如圖1進一步所示，發電單元丨19進一步包括次蒸汽消耗 裝置124 ^在該例示性實施例中，次蒸汽消耗裝置124為輔 助蒸Ά渴輪機。輔助蒸汽渴輪機12 4可為背壓滿輪機。輔 助蒸渴輪機124麵接至輔助發電機152。輔助發電機152 163487.doc 201247995 產生電力152A，其可提供至電網、工廠電網或其他局部能 源供應（未圖示）。提供至電網之能量之量可視電網負載要 求而增加或減小。該電網負載要求可為輔助蒸汽渦輪機 124之速度控制提供設^點。在_實施例十，該設定點可 具有基於輔助汽輪機丨24之排出蒸汽壓力之過負載。在另 一實施例中，設置輔助汽輪機124之排汽壓力以維持及/或 偏置發電單元U9及氣體回收單元13〇之一個或多個控制 器。該等控制器可使用比例積分微分（piD)控制及/或模型 預測控制或其他控制方法及/或蒸汽流裝置維持經輔助蒸 汽管路124a至酸氣回收單元13〇之蒸汽的品質。 氣體回收單元13〇可為酸氣擷取及回收單元。氣體回收 單元130包括C〇2吸收單元13〇&及c〇2再生單元13〇^在一 實施例中，氣體回收單元130可為基於胺之洗滌單元。在 一實施例中，氣體回收單元13〇可為供c〇2擷取之先進胺 法。在一實施例中，該先進胺法可為包括基質汽提組態之 雙基質方案。 C〇2吸收單元i30a包括c〇2吸收器（吸收器）231。c〇2再生 單元130b包括兩個或兩個以上再生塔153 ^ (該等兩個或兩 個以上再生塔153之各再生塔包括至少一個再沸器mo。） 在一實施例中，一或多個再生塔可具有兩個或兩個以上再 彿器。兩個或兩個以上再生塔丨53之配置可稱為基質汽提 組態。在該例示性實施例中，該等兩個或兩個以上再生炫 153包括高壓（HP)再生塔154及相連之第一再沸器ΐ4ι及低 壓（LP)再生塔155及相連之第二再沸器142。 163487.doc 201247995 自蒸π鋼爐單元11()經饋料管路2仏向吸收器⑶提供含 有。02之廢氣流。在一實施例令，廢氣可在提供至Co:吸 收器23 1則藉由廢氣去硫單元（未圖示）及/或冷卻單元（未圖 示）處理。在OV及收器231中，廢氣與藉由吸收自該廢氣 :除(：〇2之洛劑溶液接觸。該溶劑溶液可為基於胺之溶劑 冷液。已移除c〇2之廢氣流自c〇2吸收器23】經由排放管路 1 b排放c〇2吸收器23 !可進一步包括流體洗蘇環路 232，流體洗務環路232可包括流體洗務泵233及流體洗條 冷卻器234以消除任何夾帶溶劑。 為再生該溶劑溶液，使自吸收器23丨底部抽出之富溶劑 溶液引入該等兩個或兩個以上再生塔153之每一塔的上半 部，且富溶劑係維持在可將c〇2於各塔内壓力下蒸去之溫 度下。維持沸點所需之熱係由與各再生塔相連之一或多個 再彿器供給。該再沸方法係由待再生溶液之一部分與適宜 胤度之熱流體之間的間接熱交換來達成。在再生過程中， 維持在其沸點下之待再生富溶劑中所含之二氧化碳經釋放 且由吸收溶液之蒸汽汽提。含有經汽提c〇2之蒸汽在再生 塔頂部排出且流經冷凝系統，使與氣態c〇2 一起流出該再 生塔之吸收溶液之蒸汽冷凝所得的液相返回至該再生汉。 在該再生塔底部，抽出熱再生吸收溶液（亦稱為貧溶劑溶 液）及再循環。 在該例示性實施例中，HP再生塔1 54及LP再生塔155藉 由循環供c〇2吸收/脫附用之溶劑溶液的流體互連系統235 與C〇2吸收器23 1互連。如圖所示’該流體互連系統包括貧 163487.doc -10· 201247995 溶液冷卻器236、半貧溶液冷卻器237、LP富溶液泵238、 HP富溶液泵239、半貧溶液/富溶液熱交換器240、半貧溶 液泵241、貧溶液/富溶液熱交換器242、貧溶液泵20及各 種管路及饋料。 來自C〇2吸收器231(自富含(：02之（：02吸收器排放）之溶 劑浴液（諸如胺溶液）’或換言之富含c〇2之溶劑，經提供 至HP再生塔154及LP再生塔155，其中自溶劑汽提出c〇2。 C〇2自HP再生塔154及Lp再生塔ι55分別經由排放管路244 及排放管路245(其合併形成排放管路246)排放。排放管路 246饋至C〇2冷卻器247，其中自（：〇2流移除殘留水分^ C02 產物流自該氣體回收單元13〇經由c〇2產物排放管路248排 放。 如圖1進一步所示，蒸汽鍋爐單元Π0經由高壓蒸汽管路 126向高壓渦輪機121提供高壓蒸汽。高壓蒸汽壓力可在約 270巴與300巴之間且溫度在約6〇(Γ(：與7〇〇c>c之間。向高壓 渦輪機121提供之高壓蒸汽依工廠總負載之比例流動。工 廠總負載為工廠100產生之電力總量。高壓蒸汽自高壓蒸 汽管路126經由辅助高壓（Hp)蒸汽管路126A分出支路且饋 至輔助渦輪機124，其耦接至輔助發電機152以產生電力。 減壓蒸汽自輔助渦輪機124排出且經輔助蒸汽管路 向氣體回收單元130提供。該減屋蒸汽可在約5巴與約20巴 之間之壓力下及在低於約300°C之溫度下提供。 向氣體回收單元13G提供之減壓蒸汽提供至料兩個或 兩個以上再生塔153。該減壓蒸汽同時以不同速率提供至 I63487.doc 201247995 該等兩個或兩個以上再生塔153之各再生塔。以不同速率 提供蒸汽可包括以不同壓力、溫度及/或流量提供蒸汽。 以不同速率向該等兩個或兩個以上再生塔153之各再生塔 提供蒸/又可用以向該等兩個或兩個以上再生塔153之各再 生塔提供不同量之能量而改良各再生塔之可控性。 在該例示性實施例中，經由輔助蒸汽管路i24a分別向HP 再生塔154及LP再生塔155之第一再沸器141及第二再沸器 142提供減壓蒸汽。在另一實施例中，減壓蒸汽提供至一 或多個再彿器。以不同速率同時向第一再沸器141及第二 再沸器142提供蒸汽。以不同速率向第一再沸器141及第二 再沸器142提供蒸汽可用以向第一再沸器141及第二再沸器 142提供不同量之能量而改良各再沸器之可控性，從而分 別改良HP再生塔154及LP再生塔155之可控性。藉由控制 蒸汽分別流至第一再沸器141及第二再沸器142之速率而改 良HP再生塔154及LP再生塔155之控制，可最小化發電單 元119之電力產生降低，或換言之，使工廠1〇〇之電力產生 才貝失最小。 第一比率計算區塊131接收來自向高壓渦輪機121提供蒸 汽之高壓蒸汽管路126及來自向辅助渦輪機ι24提供蒸汽之 輔助HP蒸汽管路126A的蒸汽流資料。第一比率計算區塊 131利用蒸汽流資料信號產生信號且輸送該信號至置於輔 助蒸管路124a上的第一控制器181。第一控制器Mi藉由 調節自次渦輪機排放蒸汽流之阻力量而調節向次渦輪機 124提供之高壓蒸汽量，及調節自輔助渦輪機124至氣體回 163487.doc . π. 201247995 收單元13 0之蒸汽流量。第一控制器丨8丨可為比例積分微分 (ΡΠ>)控制閥、模型預測控制（MPC)閥、或使用另一控制律 調節及/或調整流經輔助蒸汽管路丨24a之蒸汽量的其他控 制器或閥。第一控制器！ 8丨接收第一設定點（R*)，其為基 於流至尚壓渦輪機121之蒸汽流量調節向輔助渦輪機i24提 供之蒸汽流量的操作設定值。第一設定點R·係依據蒸汽鍋 爐單元110及氣體回收單元130之負載確定，亦即，產生蒸 汽總量、產生C〇2總量及所要之c〇2擷取百分比。在另一 實施例中，一或多個控制器可置於輔助蒸汽管路124及/或 辅助蒸汽管路124a上以控帝j向辅助蒸汽渴輪機124及/或氣 體回收單元130提供之蒸汽量。 第一比率計算區塊丨3丨及第一控制器丨8丨可依向至少一個 I /飞渦輪機120知；供之高壓蒸汽量的比例控制向辅助渦輪 機124提供之蒸汽流t。向i少一㈣汽渴輪機提供之蒸 ’八量與發電單元125產生之電力125成比例，發電單元125 產生之電力125與蒸汽鍋爐單元11〇產生之酸氣量成比例。 換言之，第一比率計算區塊131及第一控制器18丨可回應如 依據间壓蒸汽流量所量測之電力需求或工廠負載的變化而 調節流至及7或流自輔助渦輪機124之蒸汽流量》 第一比率計算區塊133可回應發電單元119產生之電力 125A的變化進-步控制自辅助渦輪機124流至氣體回收單 3〇的蒸汽流量。第二比率計算區塊133接收來自發電單 7L 125產生電力125八及辅助高壓蒸汽管路η从向輔助蒸汽 渦輪機124提供蒸汽的輸入值。回應發電單元"9產生電力 163487.doc 201247995 125A之變化，第二比率計算區塊133向第二控制器134提供 控制信號，該信號係基於發電單元產生之電力與流至輔助 渦輪機124之蒸汽流量的比率。 第二控制器1 34將該信號與第二設定點R·♦進行比較，且 調整或調節經輔助蒸汽管路124a流至氣體回收單元13〇之 蒸汽量。第二控制器134可為pid控制閥、MPC閥、或使用 另一控制律調節及/或調整流經輔助蒸汽管路12牦之蒸汽 量的其他控制器或閥。該第二設定點R··為依據蒸汽鍋爐 單元110及氣體回收單元130之負載所確定之操作輸入值， 亦即，產生蒸汽總量、產生c〇2總量及所要之c〇2擷取百 分比。以此方式，第二比率計算區塊丨33及第二控制器提 供另外的流量控制以進一步調節流至氣體回收單元13〇之 蒸汽流量。在另一實施例中，一或多個比率計算區塊及/ 或使用PID、MPC或其他控制律之控制器可用以調節各種 成分之間之流動。 根據本發明系統及方法中提供之實施例，流至輔助渦輪 機以之蒸汽流量係依卫们⑽產生之電力的比例加以控 制。換言之，工廠100產生的電力愈多，貝4供給輔助滿輪 機124利用㈣汽愈多，及酸氣回收單元13〇可利用之蒸汽 愈多。因為工廠負載變化，所以此舉提供可預見的粗略控 制作用。 在另—實施例中，流至輔助渦輪機m之蒸汽與向出 輪機121提供之蒸汽的比率可使用—或多個制各種控 律(諸如(但不限於)PID控制及Mpc控制)的控制器計算及 163487.doc •14· 201247995 持固疋值。在一實施例巾，控制器可為比率卿控制器。 在β實施例中，流至輔助渦輪機124之蒸汽與向Hp渦輪機 121提供之蒸汽的計算比率可向Hp渦輪機速度控制提供設 疋點以使因至輔助渦輪機之流量節流所致之壓力損失至最 低。有：壓力損失可能是因為渦輪機出口閥之節流作用。 在另實知例中，輔助蒸汽管路！ 24a之排汽麼力信號可用 以向第比率叶算區塊13 1提供反饋信號以便保持輔助渦 輪機124之排出蒸汽壓力。 在另 列中，使用控制方法（諸如（但不限於）piD控 制律及MPC控制律）之—或多個其他控制器可進—步控制 向氣體回收單元130提供之蒸汽量。在-實施例中，該一 或多個其他控制器可使用自工廨1〇〇内各種成分程序流獲 ，之溫度量測值及/或組成量測值進一步控制向氣體回收 單元130提供之蒸汽量。舉例而言，低壓（Lp)再生塔之 頂段塔溫可用於設定第二再沸器142之再沸器負載。基於 該再沸器負載’諸如（但不限於）比率piD控制器之另一控 制器可用於維持第-再沸器141與第二再沸器142之再沸器 負載的比率。以此方式，該溶劑維持在臨界溫度或低於臨 界溫度，以便避免C〇2自該溶劑過度汽提及汽提不足。此 舉使再循環至吸收器231之溶劑的⑺2貧負載維持最佳，藉 此維持該方法之總效率。 控制自輔助渦輪機124至該至少一個再沸器14〇之蒸汽可 用以控制C〇2在HP再生塔154及LP再生塔155中的再生，因 為自輔助渦輪機124流至第一再^141及第二再}·弗器142 163487.doc 201247995 的蒸汽流量可用以控制HP再生塔1 54及LP再生塔！ 55之溫 度。 如圖1所示，蒸汽分支位置一般顯示於蒸汽管路上。然 而，本發明圖1及後續諸圖意欲包括在提供所要蒸汽品質 之蒸汽源的管路或組件位置中將蒸汽分支。舉例而言蒸 汽可自熱交換器、冷凝器、旁路、渦輪機結構或提供所要 。。質之蒸汽的其他蒸汽流通組件分支。 圖2根據本發明之另一實施例說明工廠2〇〇之示意性簡化 方法圖。工廠200之主要組件與上文參考圖i之工廠1〇〇所 不及所述相同。然而，在該實施例中，至輔助渦輪機i Μ 之蒸汽在HP渦輪機121與IP渦輪機122之間之1?蒸汽管路 21〇中分支且經由汴蒸汽管路210A提供至輔助渴輪機124。 在一實施例中，IP蒸汽管路2】〇中之蒸汽在約5〇巴與約6〇 巴之間。在另一實施例中，Ip蒸汽管路21〇中之蒸汽在約 58巴與約60巴之間。在另一實施例中，Ip蒸汽管路2丨〇中 之蒸汽在約450t與約620t之間。在另一實施例中，…蒸 汽管路210中之蒸汽在約48〇。〇與約52〇t之間。在另一實 施例中，IP蒸汽管路中之壓力為約5〇〇<t。 圖3根據本發明之另一實施例說明工廠之示意性簡七 圖工廠3 00之主要組件與上文參考圖1之工廠]〇〇^ 不及所述相同。然而’至輔助渦輪機124之蒸汽在⑺渦輕 機1 22與LP渦輪機1 23之間之LP蒸汽管路3 1 〇中分支。 1Γ施例中’ LP蒸A管路3 I 〇令之蒸汽在約3巴與約: 巴之間。在另-實施例中，LP蒸汽管路川中之蒸汽在心 I63487.doc 16 201247995 巴與約6巴之間。在另一實施例中，Lp管路3丨〇中之蒸汽為 約5巴。在另一實施例中，在1^饋料管路3丨〇中之蒸汽在約 300°C與4G0°C之間。在另-實施例巾，Lp蒸汽管路中之蒸 汽在約340°C與40(TC之間。在另一實施例中，匕？蒸汽管路 中之壓力為約400。(：。 圖4根據本發明之另一實施例說明工廠4〇〇之示意性簡化 方法圖。工廠400之主要組件與上文參考圖1之工廠100所 不及所述相同。然而，在該實施例中，自辅助鋼爐4⑺向 輔助堝輪機124提供蒸汽。因為提供輔助鍋爐410，所以至 酸氣回收單元130之廢氣流與熱輸入經去輕。在一實施例 中，s主鍋爐之負載變化時，辅助鍋爐41〇之負載改變。 輔助銷爐之負載可藉由比率PID控制器改變H維持輔 助鍋爐410與蒸汽鍋爐單元丨1〇所產生之蒸汽之比率。在另 實施例+，輔助鋼爐41()之負載係基於饋至蒸汽銷爐單 凡U〇之燃料的變化、藉由改變馈至輔助鋼爐410之燃料而 改變》 在該例示性實施例中，第二比率計算區塊433計算經辅 助鋼爐燃料饋料官路彻饋至辅助鋼爐川之燃料流量與經 瘵’飞鍋爐早元燃料饋料管路452饋至蒸汽鍋爐單元之燃 料挪里的比率。第二比率計算區塊433向PID控制器455提 供辅助鋼爐410與蒸汽鋼爐單元110之燃料流量的比率， ▲控制器455將遠比率與所提供之燃料比設定點R，進行比 較向輔助鋼爐燃料饋料管路中之流量裝置_提供流量 I63487.doc •17· 201247995 圖5根據本發明之另-實施例說明工廠500之示意性簡化 方法圖。工廠500之主要組件與上文參考圖丨之工廠1〇〇所 :及所述相同。在該實施例中，次蒸汽消耗裝置似為蒸 〜昆合器。蒸汽混合器524可為蒸汽飽和器。在另一實施 例中’次蒸汽消耗裝置524可為接收一或多種具有相同或 不同蒸八αα質之蒸汽饋料及產生所要蒸汽品質之所得蒸汽 排放的蒸 >飞裝置。蒸汽混合器524接收具有相同或相似蒸 汽品質之蒸汽馈料及合併不同蒸汽饋料以產生所要蒸汽品 質之蒸汽排放。在一實施例中’該蒸汽排放為飽和蒸汽排 放。蒸汽饋料可為蒸汽、飽和蒸汽或過飽和蒸汽與水之任 何組合。向蒸汽混合器524提供的蒸汽來自蒸汽鍋爐單元 no及來自發電單元119中之不同蒸汽分支。 銷爐單元110包括主鍋爐環路u〇a及次鍋爐環路u〇b。 主鍋爐環路110a經由主饋料管路1113接收水且經由高壓蒸 '/ία管路126排放蒸汽。次鍋爐環路丨1〇b經次饋料管路11 接收水且經次蒸汽管路516排放蒸汽。在一實施例中，經 由次蒸汽管路5 16所排放之蒸汽為高壓蒸汽。 蒸汽混合器524自次蒸汽管路516接收蒸汽。在一實施例 中，來自次蒸汽管路5 16之蒸汽在約250巴至約320巴之間 之麗力下及在約58〇t：與約70(TC之間溫度下提供至蒸汽混 合器524。在另一實施例中，次蒸汽管路516在約28〇巴至 約300巴之間之壓力下及在約6〇(Tc與約67〇t：之間之溫度 下向蒸汽混合器510提供蒸汽。 如圖5所示，向蒸汽混合器524進一步提供的蒸汽來自發 163487.doc .18- 201247995 電單元11 9，包括一或多個以下來源：來自HP蒸汽管路1 26 經過輔助HP蒸汽管路126A之HP蒸汽；來自HP渦輪機121 與IP渦輪機122之間之IP蒸汽饋料管路2 10經過輔助IP蒸汽 管路210A之IP蒸汽；來自IP渦輪機122與LP渦輪機123之間 之LP蒸汽管路310經過輔助LP蒸汽管路3 10a之LP蒸汽；及 來自由LP渦輪機123排放蒸汽之排放蒸汽管路520經過輔助 排放蒸汽管路520A之排放蒸汽。 在一實施例中，來自次蒸汽管路5 1 6之蒸汽係在約500°C 與約600°C之間。在另一實施例中，來自次蒸汽管路5丨6之 蒸汽係在約510°C與約565t之間β在另一實施例中，來自 次蒸汽管路5 16之蒸汽係在約1 5〇巴與約1 75巴之間。在另 一實施例中，來自次蒸汽管路之蒸汽係在約丨6〇巴與約1 65 巴之間。在一實施例中，來自輔助排放蒸汽管路之蒸汽係 在約0.1巴與約0.2巴之間。 工廠500進一步包括接收來自次蒸汽排放管路5丨6及111> 蒸汽管路1 26之流量資料的比率計算區塊53(^比率計算區 塊530回應發電單元119之負載向控制器581提供控制信 號。控制器5 81將該信號與所提供之設定點R"進行比較且 向控制單凡540發送控制信號。控制器58丨可為比例積分微 分（PID)控制閥、模型預測控制（Mpc)閥、或使用另一控制 律來凋節及/或調整流經次蒸汽排放管路5丨6之蒸汽量的其 他控制益或閥。該設定點R*係依據蒸汽鍋爐單元丨1〇及氣 體回收單元130之負載確定，亦目P，產生蒸汽總量、產生 C〇2總量及所要之c〇2擷取百分比。 163487.doc 19 201247995 产=元540可”算箱。控制單元-向提供蒸汽至蒸 二524之蒸八管路上的一或多個流量控制裝置…提 供㈣信號，從而以產生經由輔助蒸汽管路加流至酸氣 回收早兀130之所要蒸氣流的方式調節及合併蒸氣流。在 -實施例中’肖減壓蒸汽可在約5巴與約2〇巴之間之塵力 下及在低於約3GG°C溫度下提供。該減壓蒸汽提供至第一 再:器141及第—再彿器142。在另—實施例中，該減壓蒸 汽提供至一或多個再滞器。控制器53〇可藉由合併一或多 :輔助蒸汽管路至蒸汽飽和器524而控制不同蒸氣流。換 言之，視發電單元119需求而定，可使用或關閉一或多個 輔助蒸汽管路以及次蒸汽管路516。 儘管已參考各個例示性實施例描述本發明，但熟習此項 技術者將瞭解，可在不偏離本發明之範疇之條件下作出各 種改變且均等物可替代其元件。另外，可進行多處修改以 使特定情況或物質適用於本發明教示而不背離其基本範 鳴。因此’希望本發明不限於作為本發明實施方式所揭示 的特定實施例，而且本發明將包括屬於隨附申請專利範圍 之範鳴内的所有實施例。 【圖式簡單說明】 圖1根據本發明之一實施例說明工廠之示意性簡化方法 圖〇 圖2根據本發明之另一實施例說明蒸汽渦輪機裝置之示 意性簡化方法圖。 圖3根據本發明之另一實施例說明蒸汽渦輪機裝置之示 163487.doc -20· 201247995 意性簡化方法圖。 圖4根據本發明之另— 意性簡化方法圖。 實施例說明蒸汽渴 輪機裝 圖5根據本發明之另 意性簡化方法圖。 一實施例說明蒸汽 馮輪機裝 【主要元件符號說明】 100 熱系統/工廠 110 主蒸汽源/蒸汽鍋爐單元 110a 主銷爐環路 ll〇b 次鍋爐環路 111a 主饋料管路 111b 次饋料管路 119 發電單元 120 121 122 123 主蒸汽消耗裝置/蒸汽渦輪機 高壓（HP)渦輪機 中壓（IP)渦輪機 低壓（LP)渦輪機 124 次蒸汽消耗裝置/辅助蒸汽渦輪檣 124a 輔助蒸汽管路 ’ 125 發電單元 125A 電力 126 高壓蒸汽管路201247995 VI. Description of the invention: [Technical field to which the invention pertains] The large system of the invention relates to a thermal power plant. More specifically, the present invention relates to a method and system for integrating process control schemes for utilizing power plant steam for carbon dioxide extraction to minimize waste heat. The present application claims the benefit of the provisional application Serial No. 61/469,915, entitled A SYSTEM AND METHOD FOR CONTROLLING WASTE HEAT FOR C02 CAPTURE, filed on March 31, 2011, which is incorporated herein by reference. The manner of full reference is incorporated herein. CROSS-REFERENCE TO RELATED APPLICATIONS RELATED APPLICATIONS RELATED APPLICATIONS RELATED APPLICATIONS RELATED APPLICATIONS PCT PCT PCT PCT PCT The assignee's U.S. Patent Application Serial No. 61/469,919 (Attorney Docket No. W09/056-0 (27849-0014)) is incorporated herein by reference in its entirety. [Prior Art] Fossil fuel and natural gas power plants are known to use steam turbines and other machines to convert heat into electricity. The combustion of the fuel produces an exhaust stream comprising an acid gas comprising carbon dioxide C02, nitrogen oxides NOx and sulfur oxides SOx. Efforts have been made to reduce acid gas emissions from these power stations, and in particular to reduce greenhouse gas emissions including CO2. Thus, the C02 capture system has been integrated into these power stations. Many advances have been made in this regard to partially and completely separate the eh generated between the fossil fuel combustion period 163487.doc 201247995, and the use of aqueous amine solutions to remove sour gas contaminants from the combustion gas stream. Aqueous solution absorption and stripping method. Gas absorption is a method of dissolving a soluble component of a gas mixture in a liquid. The gas/liquid contact can be in countercurrent or cocurrent contact, with countercurrent contact being most commonly employed. Stripping is essentially reverse absorption because it involves the transfer of volatile components from the liquid mixture to the gas. In a typical carbon dioxide removal process, carbon dioxide is removed by absorption from a combustion gas, and then the solvent is used to regenerate the solvent and extract carbon dioxide contained in the solvent. Once removed from combustion gases and other gases, carbon dioxide can be extracted and compressed for many applications including sequestration, sterol production, and tertiary petroleum recovery. To regenerate the absorption solution, the rich solvent withdrawn from the bottom of the absorption column is introduced into the upper half of the stripping crucible, and the rich solvent is maintained under pressure at or near its boiling point. The heat required to maintain this high temperature is reboiled by the absorption solution contained in the stripping column, which requires energy and thus increases the overall operating cost. Therefore, it is necessary to provide a cost-saving and efficient operation of energy to the reboiler to regenerate the supported aqueous amine stream. SUMMARY OF THE INVENTION One object of the present invention is to provide a system and method for efficiently providing heat to an acid gas absorption/stripping process integrated with a steam power generation system. Another object of the present invention is to optimize the overall efficiency of the power plant by providing energy to the sour gas extraction system by using a special configuration of steam branches (extraction points) from different turbine stages and water and/or steam cycle locations. . Another object of the present invention is to provide a special configuration of steam branches (extraction points) from different full turbine stages and water and/or 163487.doc 201247995 locomotive cycle locations to provide energy to the sour gas extraction system. The take-up system can be designed as a new system or improved based on existing power generation system designs. Another object of the present invention is to provide a process control scheme for integrating steam power generation load and energy generation for acid gas extraction. Accordingly, one of the objects of the present invention may be to reduce energy consumption, depending on the operating parameters and design parameters of known techniques for acid picking. Moreover, it is an object of the present invention to use this technique to absorb sour gas to reduce environmental, health and/or economic improvements in chemical emissions. In one aspect, the disclosed plant includes: a boiler unit that produces steam, a power generation unit that includes at least one power generation turbine that receives steam from the boiler unit, and a gas recovery unit that includes two or more regeneration towers, A secondary steam source for two or more regeneration towers, and a controller configured to regulate the flow of steam to two or more regeneration towers. The controller includes a control strategy that determines the flow of steam from the steam source to each of the two or more regeneration columns based on plant load parameters. In another aspect, a method of providing steam to a gas recovery unit is disclosed, the method comprising controlling a flow of steam to two or more regeneration columns of a gas recovery unit based on load parameters of the power generation unit. [Embodiment] Referring now to the drawings, which are exemplary embodiments, Specific embodiments of systems and methods for providing energy to acid gas recovery using power generation steam in accordance with the present invention are described below with reference to the drawings. 163487.doc 201247995 Figure 1 illustrates a schematic simplified method diagram of a factory 1〇〇 in accordance with an embodiment of the present invention. In the embodiment, the & system 100 can be a thermal power plant. In another embodiment, the plant may be a plant or plant that includes a combustion unit that produces carbon dioxide-containing exhaust gas and at least one steam unit. The steam unit can be a steam turbine power unit. As shown in Fig. 1, the plant 100 includes a main steam source 11A, a power generating unit 119, and a gas recovery unit 130. In the exemplary embodiment, main steam source 1 is a steam boiler unit. The steam boiler unit crucible 10 may include one or more steam boilers that generate steam using fossil fuels. The fuel may be coal, peat, biomass, syngas/fuel, natural gas, or other carbon fuel source that, when combusted, produces Exhaust gas containing gaseous pollutants such as sour gas. The power generation unit 119 includes a main steam consuming device 120 and a power generation unit 125. In the exemplary embodiment, main steam consuming device 12 is one or more steam turbines. One or more steam turbines 12A are coupled to power generating unit i25 to provide mechanical energy to generator 125 to produce electrical power 125A. This power can be supplied to the grid (not shown). In the exemplary embodiment, one or more steam turbines 120 include a high pressure (HP) turbine 121, a medium pressure (ip) turbine 122, and a low pressure (LP) turbine 123. In another embodiment, one or more steam full turbines 120 may include a plurality of combinations of turbines having similar or different operating pressures. As further shown in FIG. 1, power generating unit 丨 19 further includes secondary steam consuming devices 124. In the exemplary embodiment, the secondary steam consuming device 124 is an auxiliary steam chiller. The auxiliary steam thirst turbine 12 4 may be a back pressure full turbine. The auxiliary steam turbine 124 is connected to the auxiliary generator 152. The auxiliary generator 152 163487.doc 201247995 generates electrical power 152A that can be provided to the grid, factory grid, or other local energy supply (not shown). The amount of energy provided to the grid can be increased or decreased depending on grid load requirements. This grid load requirement provides a point of control for the speed control of the auxiliary steam turbine 124. In the tenth embodiment, the set point may have an overload based on the exhaust steam pressure of the auxiliary turbine 丨24. In another embodiment, the exhaust steam pressure of the auxiliary turbine 124 is set to maintain and/or bias one or more of the power generating unit U9 and the gas recovery unit 13A. The controllers may maintain the quality of the steam passing through the auxiliary steam line 124a to the sour gas recovery unit 13 using proportional integral derivative (piD) control and/or model predictive control or other control methods and/or steam flow means. The gas recovery unit 13 can be an acid gas extraction and recovery unit. The gas recovery unit 130 includes a C〇2 absorption unit 13〇& and a c〇2 regeneration unit 13〇 In one embodiment, the gas recovery unit 130 may be an amine-based washing unit. In one embodiment, the gas recovery unit 13A can be an advanced amine process for c〇2 extraction. In one embodiment, the advanced amine process can be a dual matrix solution comprising a matrix stripping configuration. The C〇2 absorption unit i30a includes a c〇2 absorber (absorber) 231. The c〇2 regeneration unit 130b includes two or more regeneration columns 153^ (each of the two or more regeneration columns 153 includes at least one reboiler mo.) In one embodiment, one or Multiple regeneration towers can have two or more refills. The configuration of two or more regeneration towers 53 can be referred to as a matrix stripping configuration. In the exemplary embodiment, the two or more regenerative 153 include a high pressure (HP) regeneration column 154 and a connected first reboiler ΐ4ι and a low pressure (LP) regeneration column 155 and a second connected reg. Boiling 142. 163487.doc 201247995 The self-steaming π steel furnace unit 11 () is supplied to the absorber (3) via the feed line 2 仏. 02 exhaust gas flow. In one embodiment, the exhaust gas may be supplied to the Co: absorber 23 1 by an exhaust gas desulfurization unit (not shown) and/or a cooling unit (not shown). In the OV and the receiver 231, the exhaust gas is contacted by the exhaust gas: in addition to (the solution of the solution of 〇2). The solvent solution may be an amine-based solvent cold liquid. The c〇2 absorber 23] discharges the c〇2 absorber 23 via the discharge line 1 b! may further include a fluid washout loop 232, which may include a fluid wash pump 233 and a fluid wash strip cooler 234 to eliminate any entrained solvent. To regenerate the solvent solution, a solvent-rich solution extracted from the bottom of the absorber 23 is introduced into the upper half of each of the two or more regeneration columns 153, and the solvent rich system Maintained at a temperature at which c〇2 can be distilled under the pressure in each column. The heat required to maintain the boiling point is supplied by one or more re-fossils connected to each regeneration column. The reboiling method is to be regenerated The indirect heat exchange between a portion of the solution and the hot fluid of suitable temperature is achieved. During the regeneration process, the carbon dioxide contained in the rich solvent to be regenerated at its boiling point is maintained and stripped by the vapor of the absorption solution. Steam containing stripped c〇2 is discharged at the top of the regeneration tower And flowing through the condensing system, returning the liquid phase obtained by condensing the vapor of the absorption solution flowing out of the regeneration tower together with the gaseous state c〇2 to the regenerative. At the bottom of the regeneration tower, extracting the heat regeneration absorption solution (also called the lean solvent) Solution) and recirculation. In the exemplary embodiment, HP regeneration column 154 and LP regeneration column 155 are absorbed by fluid interconnect system 235 and C〇2 circulating a solvent solution for c〇2 absorption/desorption. The devices 23 1 are interconnected. As shown, the fluid interconnect system includes a lean 163487.doc -10·201247995 solution cooler 236, a semi-lean solution cooler 237, an LP rich solution pump 238, an HP rich solution pump 239, and a half. Lean solution/rich solution heat exchanger 240, semi-lean solution pump 241, lean solution/rich solution heat exchanger 242, lean solution pump 20 and various lines and feeds. From C〇2 absorber 231 (self-rich ( A solvent bath (such as an amine solution) of 02 (: 02 absorber discharge) or, in other words, a solvent rich in c〇2, is supplied to the HP regeneration column 154 and the LP regeneration column 155, wherein the solvent is stripped from the solvent. 2. C〇2 from HP regeneration tower 154 and Lp regeneration tower ι55 via discharge line 244, respectively The discharge line 245 (which merges to form the discharge line 246) is discharged. The discharge line 246 is fed to the C〇2 cooler 247, wherein the residual moisture is removed from the (:〇2 stream) C02 product stream from the gas recovery unit 13〇 Discharged via c〇2 product discharge line 248. As further shown in Fig. 1, steam boiler unit 提供0 provides high pressure steam to high pressure turbine 121 via high pressure steam line 126. The high pressure steam pressure can be between about 270 and 300 bar and The temperature is between about 6 Torr (: (with 7 〇〇 c > c.) The high pressure steam supplied to the high pressure turbine 121 flows in proportion to the total load of the plant. The total plant load is the total amount of electricity generated by plant 100. The high pressure steam exits the high pressure steam line 126 via the auxiliary high pressure (Hp) steam line 126A and is fed to the auxiliary turbine 124, which is coupled to the auxiliary generator 152 to generate electricity. The reduced pressure steam is discharged from the auxiliary turbine 124 and supplied to the gas recovery unit 130 via the auxiliary steam line. The reduced house steam can be provided at a pressure between about 5 bar and about 20 bar and at a temperature below about 300 °C. The reduced pressure steam supplied to the gas recovery unit 13G is supplied to two or more regeneration columns 153. The reduced pressure steam is simultaneously supplied to the respective regeneration towers of the two or more regeneration columns 153 at I63487.doc 201247995 at different rates. Providing steam at different rates may include providing steam at different pressures, temperatures, and/or flows. Steaming is provided to each of the two or more regeneration columns 153 at different rates to provide different amounts of energy to each of the two or more regeneration columns 153 to improve regeneration. The controllability of the tower. In the exemplary embodiment, the reduced pressure steam is supplied to the first reboiler 141 and the second reboiler 142 of the HP regeneration column 154 and the LP regeneration column 155 via the auxiliary steam line i24a, respectively. In another embodiment, the reduced pressure steam is provided to one or more refills. Steam is supplied to the first reboiler 141 and the second reboiler 142 at different rates simultaneously. Supplying steam to the first reboiler 141 and the second reboiler 142 at different rates can be used to provide different amounts of energy to the first reboiler 141 and the second reboiler 142 to improve the controllability of each reboiler. Thereby, the controllability of the HP regeneration tower 154 and the LP regeneration tower 155 is improved, respectively. By controlling the flow of the steam to the first reboiler 141 and the second reboiler 142 to improve the control of the HP regeneration tower 154 and the LP regeneration tower 155, the power generation reduction of the power generation unit 119 can be minimized, or in other words, The power generated by the factory is minimized. The first ratio calculation block 131 receives steam flow data from a high pressure steam line 126 that supplies steam to the high pressure turbine 121 and an auxiliary HP steam line 126A that supplies steam to the auxiliary turbine ι 24. The first ratio calculation block 131 generates a signal using the steam flow data signal and delivers the signal to the first controller 181 placed on the auxiliary steam line 124a. The first controller Mi regulates the amount of high pressure steam supplied to the secondary turbine 124 by adjusting the amount of resistance from the secondary turbine exhaust steam flow, and regulates the self-assisted turbine 124 to the gas return 163487.doc. π. 201247995 receiving unit 13 0 Steam flow. The first controller 丨8丨 may be a proportional integral derivative (ΡΠ>) control valve, a model predictive control (MPC) valve, or use another control law to adjust and/or adjust the amount of steam flowing through the auxiliary steam line 丨24a. Other controllers or valves. First controller! The first set point (R*) is received, which is an operational set point for adjusting the steam flow to the auxiliary turbine i24 based on the steam flow to the still-pressure turbine 121. The first set point R· is determined based on the load of the steam boiler unit 110 and the gas recovery unit 130, that is, the total amount of steam generated, the total amount of C〇2 produced, and the desired percentage of c〇2 extraction. In another embodiment, one or more controllers may be placed on the auxiliary steam line 124 and/or the auxiliary steam line 124a to control the steam supplied to the auxiliary steam thirst turbine 124 and/or the gas recovery unit 130. the amount. The first ratio calculation block 丨3丨 and the first controller 丨8丨 are compliant with the at least one I/fly turbine 120; the ratio of the high pressure steam amount is controlled to provide the steam flow t to the auxiliary turbine 124. The steam supplied to the i(1) steam turbine is proportional to the power 125 generated by the power generating unit 125, and the power 125 generated by the power generating unit 125 is proportional to the amount of acid gas produced by the steam boiler unit 11〇. In other words, the first ratio calculation block 131 and the first controller 18 can respond to the flow of steam to or from the auxiliary turbine 124 in response to changes in power demand or plant load as measured by the inter-pressure steam flow. The first ratio calculation block 133 can control the flow of steam from the auxiliary turbine 124 to the gas recovery unit 3 in response to the change in the power 125A generated by the power generation unit 119. The second ratio calculation block 133 receives an input value from the power generation unit 7L 125 generating power 125 and the auxiliary high pressure steam line η from supplying steam to the auxiliary steam turbine 124. In response to the power generation unit "9 generating a change in power 163487.doc 201247995 125A, the second ratio calculation block 133 provides a control signal to the second controller 134 based on the power generated by the power generation unit and the steam flowing to the auxiliary turbine 124 The ratio of traffic. The second controller 134 compares the signal with the second set point R·♦ and adjusts or adjusts the amount of steam flowing through the auxiliary steam line 124a to the gas recovery unit 13〇. The second controller 134 can be a pid control valve, an MPC valve, or other controller or valve that regulates and/or adjusts the amount of steam flowing through the auxiliary steam line 12 using another control law. The second set point R·· is an operation input value determined according to the load of the steam boiler unit 110 and the gas recovery unit 130, that is, the total amount of steam generated, the total amount of generated c〇2, and the desired c〇2 extraction. percentage. In this manner, the second ratio calculation block 丨33 and the second controller provide additional flow control to further adjust the flow of steam to the gas recovery unit 13〇. In another embodiment, one or more ratio calculation blocks and/or controllers using PID, MPC or other control laws may be used to adjust the flow between the various components. In accordance with an embodiment provided in the system and method of the present invention, the flow of steam to the auxiliary turbine is controlled by the proportion of power generated by the turbines (10). In other words, the more power generated by the plant 100, the more the steam is supplied to the auxiliary full wheeler 124, and the more steam is available to the acid gas recovery unit 13 . This provides predictable coarse control because of factory load changes. In another embodiment, the ratio of the steam flowing to the auxiliary turbine m to the steam supplied to the outflow turbine 121 may be used - or a plurality of controllers of various controls such as, but not limited to, PID control and Mpc control. Calculation and 163487.doc •14· 201247995 Holding value. In an embodiment, the controller can be a ratio controller. In the beta embodiment, the calculated ratio of steam flowing to the auxiliary turbine 124 to the steam provided to the Hp turbine 121 may provide a set point to the Hp turbine speed control to cause pressure loss due to flow throttling to the auxiliary turbine to lowest. Yes: The pressure loss may be due to the throttling of the turbine outlet valve. In another example, the auxiliary steam line! The exhaust force signal of 24a can be used to provide a feedback signal to the first ratio abacus block 13 1 to maintain the exhaust steam pressure of the auxiliary turbine 124. In the alternative, the amount of steam supplied to the gas recovery unit 130 can be further controlled using control methods such as, but not limited to, piD control law and MPC control law. In an embodiment, the one or more other controllers may be streamed using various component programs within the self-processing unit, and the temperature measurements and/or component measurements further control the supply to the gas recovery unit 130. The amount of steam. For example, the top column temperature of the low pressure (Lp) regeneration column can be used to set the reboiler duty of the second reboiler 142. Another controller based on the reboiler load' such as, but not limited to, a ratio piD controller can be used to maintain the ratio of reboiler loading of the first reboiler 141 to the second reboiler 142. In this manner, the solvent is maintained at or below the critical temperature in order to avoid excessive purge of C〇2 from the solvent to mention insufficient stripping. This maintains the (7) 2 lean load of the solvent recycled to the absorber 231 to maintain optimum, thereby maintaining the overall efficiency of the process. The steam controlling the self-assisted turbine 124 to the at least one reboiler 14 can be used to control the regeneration of C〇2 in the HP regeneration column 154 and the LP regeneration column 155 because the self-assisted turbine 124 flows to the first re-141 and The steam flow of 201247995 can be used to control the HP Regeneration Tower 1 54 and the LP regeneration tower! 55 degrees of temperature. As shown in Figure 1, the steam branch location is generally shown on the steam line. However, Figure 1 and subsequent figures of the present invention are intended to include steam branching in a pipeline or assembly location that provides a source of steam of the desired steam quality. For example, the steam can be supplied from a heat exchanger, a condenser, a bypass, a turbine structure, or the like. . Branch of other steam circulation components of the quality steam. Fig. 2 is a diagram showing a schematic simplified method of a factory 2 according to another embodiment of the present invention. The main components of the factory 200 are the same as those described above with reference to the factory of Figure i. However, in this embodiment, the steam to the auxiliary turbine i 分支 branches in the 1 steam line 21 之间 between the HP turbine 121 and the IP turbine 122 and is supplied to the auxiliary chiller turbine 124 via the helium steam line 210A. In one embodiment, the steam in the IP steam line 2 is between about 5 Torr and about 6 Torr. In another embodiment, the steam in the Ip steam line 21 is between about 58 bar and about 60 bar. In another embodiment, the steam in the Ip steam line 2 is between about 450 tons and about 620 tons. In another embodiment, the steam in the steam line 210 is about 48 Torr. 〇 between about 52〇t. In another embodiment, the pressure in the IP steam line is about 5 Torr < t. Figure 3 illustrates a schematic diagram of a factory in accordance with another embodiment of the present invention. The main components of the factory 300 are the same as those described above with reference to Figure 1. However, the steam to the auxiliary turbine 124 branches in the LP vapor line 3 1 ( between the (7) vortex machine 1 22 and the LP turbine 1 23 . 1) In the example, 'LP steam A line 3 I 〇 order steam between about 3 bar and about: bar. In another embodiment, the steam in the LP steam line is between I63487.doc 16 201247995 and about 6 bar. In another embodiment, the steam in the Lp line 3 is about 5 bar. In another embodiment, the steam in the feed line 3 is between about 300 ° C and 4 G0 ° C. In another embodiment, the steam in the Lp steam line is between about 340 ° C and 40 (TC. In another embodiment, the pressure in the steam line is about 400. (: Figure 4. A schematic simplified method diagram of a factory 4 is illustrated in accordance with another embodiment of the present invention. The main components of the plant 400 are the same as described above with reference to the factory 100 of Figure 1. However, in this embodiment, self-assisted The steel furnace 4 (7) supplies steam to the auxiliary turbine 124. Since the auxiliary boiler 410 is provided, the exhaust gas flow and the heat input to the acid gas recovery unit 130 are lightened. In one embodiment, when the load of the main boiler changes, the auxiliary boiler The load of the auxiliary pin furnace is changed. The load of the auxiliary pin furnace can be changed by the ratio PID controller to maintain the ratio of the steam generated by the auxiliary boiler 410 and the steam boiler unit 。1〇. In another embodiment, the auxiliary steel furnace 41() The load is varied based on the change in fuel fed to the steam pin furnace, by varying the fuel fed to the auxiliary steel furnace 410. In the exemplary embodiment, the second ratio calculation block 433 is calculated assisted. Steel furnace fuel feed official road to the auxiliary The ratio of the fuel flow of the furnace to the fuel injection to the steam boiler unit via the 瘵 'flying boiler early fuel supply line 452. The second ratio calculation block 433 provides the auxiliary steel furnace 410 and steam to the PID controller 455. The ratio of the fuel flow rate of the steel furnace unit 110, ▲ the controller 455 compares the far ratio to the supplied fuel ratio set point R, to the flow device in the auxiliary steel furnace fuel feed line _ provides the flow rate I63487.doc • 17 · 201247995 Figure 5 illustrates a schematic simplified process diagram of a plant 500 in accordance with another embodiment of the present invention. The main components of the plant 500 are the same as those described above with reference to the drawings: and in this embodiment The secondary steam consuming device appears to be a steaming-steamer. The steam mixer 524 can be a steam saturator. In another embodiment, the secondary steam consuming device 524 can receive one or more of the same or different steamed alpha alpha alpha a steam feed and a steaming device that produces the resulting steam emissions of the desired steam quality. The steam mixer 524 receives steam feeds having the same or similar steam quality and combines different steam feeds to produce the desired Steam quality steam emissions. In one embodiment 'the steam emissions are saturated steam emissions. The steam feed may be steam, saturated steam or any combination of supersaturated steam and water. The steam supplied to steam mixer 524 is from a steam boiler unit No and different steam branches from the power generation unit 119. The pin furnace unit 110 includes a main boiler circuit u〇a and a secondary boiler circuit u〇b. The main boiler circuit 110a receives water via the main feed line 1113 and passes through the high pressure. The steaming unit 126 discharges steam. The secondary boiler loop 丨1〇b receives water through the secondary feed line 11 and discharges steam through the secondary steam line 516. In one embodiment, via the secondary steam line 5 16 The discharged steam is high pressure steam. Steam mixer 524 receives steam from secondary steam line 516. In one embodiment, the steam from the secondary steam line 516 is provided to the steam mixer at a temperature between about 250 bar and about 320 bar and at a temperature between about 58 〇t: and about 70 (TC). 524. In another embodiment, the secondary steam line 516 is directed to the steam mixer at a pressure of between about 28 Torr and about 300 bar and at a temperature of between about 6 Torr (Tc and about 67 〇t: Steam is provided at 510. As shown in Figure 5, the steam further supplied to steam mixer 524 is from 163487.doc.18-201247995 electrical unit 119, including one or more of the following sources: from HP steam line 1 26 assisted HP steam of HP steam line 126A; IP steam feed line 2 10 between HP turbine 121 and IP turbine 122 passes IP steam of auxiliary IP steam line 210A; between IP turbine 122 and LP turbine 123 The LP steam line 310 passes through the LP steam of the auxiliary LP steam line 3 10a; and the exhaust steam from the discharge steam line 520 discharged by the LP turbine 123 through the auxiliary discharge steam line 520A. In one embodiment, from The steam of steam line 516 is between about 500 ° C and about 600 ° C. In another embodiment, the steam from the secondary steam line 5丨6 is between about 510 ° C and about 565 t. In another embodiment, the steam from the secondary steam line 5 16 is about 15 〇. The bar is between about 1 and 75 bar. In another embodiment, the steam from the secondary steam line is between about 6 Torr and about 1 65 bar. In one embodiment, from the auxiliary venting steam line The steam is between about 0.1 bar and about 0.2 bar. The plant 500 further includes a ratio calculation block 53 (^ ratio calculation area) for receiving flow data from the secondary steam discharge lines 5丨6 and 111> Block 530 provides a control signal to controller 581 in response to the load of power generating unit 119. Controller 581 compares the signal to the provided setpoint R" and sends a control signal to control unit 540. Controller 58 may be a ratio Integral derivative (PID) control valve, model predictive control (Mpc) valve, or other control benefit or valve that uses another control law to deflate and/or adjust the amount of steam flowing through the secondary steam discharge line 5丨6. The set point R* is based on the steam boiler unit 〇1〇 and the gas recovery unit 130 The determination, also the target P, the total amount of steam produced, the total amount of C〇2 produced and the desired percentage of c〇2. 163487.doc 19 201247995 Production = yuan 540 can be calculated. Control unit - provide steam to steam One or more flow control devices on the steam line of the second 524 ... provide a (four) signal to regulate and combine the vapor streams in a manner that produces a desired vapor stream that is fed to the acid gas recovery early stream 130 via the auxiliary steam line. In the embodiment, the 'mode vacuum pressure steam can be provided at a dust pressure between about 5 bar and about 2 bar and at a temperature below about 3 GG C. The reduced pressure steam is supplied to the first reactor 141 and the second burner 142. In another embodiment, the reduced pressure steam is provided to one or more retarders. The controller 53 can control the different vapor streams by combining one or more of the auxiliary steam lines to the steam saturator 524. In other words, depending on the demand of the power generating unit 119, one or more auxiliary steam lines and secondary steam lines 516 can be used or shut down. While the invention has been described with respect to the various embodiments of the present invention, it is understood that various modifications may be In addition, many modifications may be made to adapt a particular situation or substance to the teachings of the invention. Therefore, the invention is not intended to be limited to the specific embodiments disclosed as the embodiments of the invention. BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 is a schematic simplified illustration of a factory in accordance with an embodiment of the present invention. FIG. 2 is a schematic illustration of a simplified simplified method of a steam turbine apparatus in accordance with another embodiment of the present invention. Fig. 3 is a diagram showing the simplified simplified method of the steam turbine apparatus according to another embodiment of the present invention. 163487.doc -20· 201247995. Figure 4 is a schematic diagram of another simplified method in accordance with the present invention. The embodiment illustrates a steam thirst turbine assembly. Figure 5 is an alternative simplified method diagram in accordance with the present invention. An embodiment illustrates a steam von turbine installation [main component symbol description] 100 thermal system / plant 110 main steam source / steam boiler unit 110a main pin furnace loop ll 〇 b secondary boiler loop 111a main feed line 111b secondary feed Line 119 Power Generation Unit 120 121 122 123 Main Steam Consumption Unit / Steam Turbine High Pressure (HP) Turbine Medium Pressure (IP) Turbine Low Pressure (LP) Turbine 124 Secondary Steam Consumption Unit / Auxiliary Steam Turbine 樯 124a Auxiliary Steam Line ' 125 Power Generation Unit 125A Power 126 High Pressure Steam Line
126A 輔助高壓（HP)蒸汽管路 氣體回收單元 163487.doc 21 130 201247995 130a C02吸收單元 130b co2再生單元 131 第一比率計算區 133 第二比率計算區 134 第二控制器 140 再沸器 141 第一再沸器 142 第二再沸器 152 輔助發電機 152A 電力 153 再生塔 154 高壓（HP)再生塔 155 低壓（LP)再生塔 181 第一控制器 200 工廠 210 IP蒸汽管路 210A 輔助IP蒸汽管路 231 吸收塔（吸收器） 231a 饋料管路 231b 排放管路 232 流體洗滌環路 233 流體洗滌泵 234 流體洗滌冷卻器 235 流體互連系統 163487.doc -22. 201247995 236 貧溶液冷卻器 237 半貧溶液冷卻器 238 LP富溶液泵 239 HP富溶液泵 240 半貧溶液/富溶液熱交換器 241 半貧溶液泵 242 貧溶液/富溶液熱交換器 243 貧溶液泵 244 排放管路 245 排放管路 246 排放管路 247 co2冷卻器 248 C〇2產物排放管路 300 工廠 310 LP蒸汽管路 310a 輔助LP蒸汽管路 400 工廠 410 輔助鍋爐 433 第二比率計算區塊 450 輔助鍋爐燃料饋料管路 452 蒸汽鍋爐單元燃料饋料管路 455 PID控制器 460 流量裝置 500 工廉 163487.doc .23· 201247995 516 520 520A 524 524a 530 540 581 HP IP LP PID R· R" 次蒸汽管路 排放蒸汽管路 輔助排放蒸汽管路 次蒸汽消耗裝置/蒸汽混合器 輔助蒸汽管路 比率計算區塊 控制單元 控制器 高壓 中亞 低壓 比例積分微分控制 第一設定點 第二設定點 163487.doc -24·126A auxiliary high pressure (HP) steam line gas recovery unit 163487.doc 21 130 201247995 130a C02 absorption unit 130b co2 regeneration unit 131 first ratio calculation area 133 second ratio calculation area 134 second controller 140 reboiler 141 first Reboiler 142 Second reboiler 152 Auxiliary generator 152A Power 153 Regeneration tower 154 High pressure (HP) regeneration tower 155 Low pressure (LP) regeneration tower 181 First controller 200 Plant 210 IP steam line 210A Auxiliary IP steam line 231 Absorption column (absorber) 231a Feed line 231b Discharge line 232 Fluid wash circuit 233 Fluid wash pump 234 Fluid wash cooler 235 Fluid interconnect system 163487.doc -22. 201247995 236 Lean solution cooler 237 Semi-poor Solution cooler 238 LP rich solution pump 239 HP rich solution pump 240 semi-lean solution/rich solution heat exchanger 241 semi-lean solution pump 242 lean solution/rich solution heat exchanger 243 lean solution pump 244 discharge line 245 discharge line 246 Discharge line 247 co2 cooler 248 C〇2 product discharge line 300 plant 310 LP steam line 310a auxiliary LP steam line 40 0 Plant 410 Auxiliary Boiler 433 Second Ratio Calculation Block 450 Auxiliary Boiler Fuel Feed Line 452 Steam Boiler Unit Fuel Feed Line 455 PID Controller 460 Flow Device 500 Lian Lian 163487.doc .23· 201247995 516 520 520A 524 524a 530 540 581 HP IP LP PID R· R" Secondary steam line discharge steam line auxiliary discharge steam line secondary steam consumption unit / steam mixer auxiliary steam line ratio calculation block control unit controller high pressure medium and low pressure ratio Integral derivative control first set point second set point 163487.doc -24·