平成 19 年度
海外炭開発高度化等調査「アジア太平洋石炭セミナー」
報 告 書

平成 20 年 3 月（独）新エネルギー・産業技術総合開発機構
委託先： 財団法人石炭エネルギーセンター

目
平成 19 年度

次

海外炭開発高度化等調査「アジア太平洋石炭セミナー」
【本

編】

1.

要約 ··································································································· 7

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講演概要 ····························································································· 15(1) 開会セッション····················································································· 15① 開会挨拶 1（中国電力ｴﾝｼﾞﾆｱﾘﾝｸﾞ学会副会長 ｼﾞｬﾝ･ｷﾞｼﾝ氏） ···················· 15② 開会挨拶 2（APEC EGCFE 議長ｽｺｯﾄ･ｽﾏｳｽ氏） ···································· 15③ 基調講演 1（科学技術省副局長ｼｭｰ･ｼﾞｬﾝ氏）········································· 17④ 基調講演 2（JAPAC 副会長・JCOAL 理事長 安藤 勝良博士）·············· 18⑤ 基調講演 3（中国華能集団公司副社長ｳｰ･ﾙｵｼ氏）··································· 19(2) 第 1 セッション「石炭の需給予測 1」 ························································ 21① 中国の石炭産業開発の政策の方向性（中国煤炭協会 ｼﾞｬﾝ･ﾖﾝ氏） ·············· 21② ﾏﾚｰｼｱにおける石炭需給予測（TNB 燃料公社 ﾋｭｰ・ﾁｬｰ・ﾛﾝ氏） ··············· 22③ ﾀｲにおける石炭需給予測（ｴﾈﾙｷﾞｰ省ｴﾈﾙｷﾞｰ政策計画庁ｻﾏﾙｼﾞｬｲ･ｽｸｽﾒｸ氏） ··· 23(3) 第 2 セッション「クリーンな石炭火力発電所」············································ 25① 中国における石炭火力発電所の開発と現状（中国工程院ﾌｧﾝ･ﾁﾘ氏） ··········· 25② 世界規模な気候変動緩和に係る技術の役割 ··········································· 26（米国環境保護庁ﾌﾗﾝｸ･ﾌﾟﾘﾝｼｵｯﾀ氏）③ ｸﾞﾘｰﾝｼﾞｪﾝ技術（中国華能集団公司ﾌｰ･ｼﾊｲ氏） ······································ 27(4) 第 3 セッション「クリーンな石炭火力発電所」············································ 28①

APEC 途上国においての CCT を促進するための環境規制の導入理由 ········ 28（米 SAIC ｼﾞｪｯﾄ･ﾌｪﾝﾃﾞｿﾝ氏）②

中国初国産 300MW 流動床ﾎﾞｲﾗ-について ··········································· 29（中国大唐集団公司ｼﾞﾝ･ﾊｵﾊ氏）③

CCT を用いた石炭火力発電所（韓国電力公社ｽﾝﾁｭﾙ･ｷﾑ博士）··············· 30(5) 第 4 セッション「石炭需給予測 2」··························································· 31①

ﾌｨﾘﾋﾟﾝにおける石炭需給予測（ｴﾈﾙｷﾞｰ省ﾚｽﾄｳﾄ･ﾀﾅｶﾞｽ氏） ······················· 31②

ｲﾝﾄﾞにおける石炭需給予測（石炭省 KS ｸﾛﾌｧ氏）·································· 33③

韓国における石炭需給予測（韓国石炭公社ｼﾞｪｴﾎ･ｷﾑ博士）······················ 34④

台湾における石炭需給予測（経済部ｼﾞｪﾝｼｪﾝ･ｽｰ氏） ······························ 35⑤日本の石炭政策（資源ｴﾈﾙｷﾞｰ庁 近藤 裕之氏） ··································· 36(6) 第 5 セッション「クリーンな石炭火力発電所」············································ 37①

環境保全技術の現状と石炭火力発電所の開発 ······································· 37（中国国電集団公司ﾜﾝ･ｿﾞﾝｸﾞ氏）

②

石炭火力発電所における省ｴﾈﾙｷﾞｰ（中国電力投資社ｼﾞﾝ･ﾄﾞﾝｸﾞﾚ氏） ·········· 38③

先進的ﾊﾟﾗﾒｰﾀｰを持った石炭火力発電所の省ｴﾈﾙｷﾞｰ開発 ·························· 40（中国貨能国際電力有限公司ﾙｰ･ｸﾞｵｴ氏）(7) 第 6 セッション「石炭供給展望」 ····························································· 41①

中国における石炭需給と石炭産業政策 ················································ 41（中国煤炭販売輸送協会ﾙｰ･ｼｬｵﾔﾝ氏）②

豪州における石炭供給展望（産業観光資源省 ﾙｲｽ･ﾀﾏｼｭｹ氏）··················· 42③

ｲﾝﾄﾞﾈｼｱにおける石炭供給展望（ｴﾈﾙｷﾞｰ･鉱物資源省ｽｸﾏ･ﾊｼﾊﾞｰﾝ博士） ······· 43④

ﾛｼｱにおける石炭供給展望（ﾛｼｱ科学ｱｶﾃﾞﾐｰｼﾍﾞﾘｱ支部ﾄﾞﾐﾄﾘｰ･ｿｺﾛﾌ氏） ······· 45⑤

ﾍﾞﾄﾅﾑにおける石炭供給展望（VINACOMIN ｷｭｰ･ｷﾑ･ﾁｪｸ博士） ··············· 47⑥

ｲﾝﾄﾞﾈｼｱの石炭開発（ｴﾈﾙｷﾞｰ･鉱物資源省ﾊｼﾞ･ﾇｻﾙﾔ博士）························· 48(8) 第 7 セッション「石炭火力発電所における省ｴﾈ・省水」 ································ 49①

低温海水淡水か適用と発電と水の生産 ················································ 49（北京国貨有限公司ｼﾞｬﾝ･ｼﾞｬﾝｸﾞﾘ氏）②

ｴﾈﾙｷﾞｰ効率向上と低公害のための低ﾘｽｸ高ﾘﾀｰﾝの TIFI tm 技術ローﾘｽｸ ········ 50（ﾌｭｴﾙﾃｯｸ社ﾘﾝﾀﾞ･ﾘﾝ博士）③

石炭火力発電所のｴﾈﾙｷﾞｰ消費評価と省ｴﾈﾙｷﾞｰ可能性解析························· 51（西安熱工研究院ﾕｰ･ｼﾝﾕﾝ氏）④

石炭火力発電所のﾘﾉﾍﾞｰｼｮﾝ（JCOAL 竹川 東明氏）···························· 52⑤中国の石炭火力発電所における省水技術の現状 ···································· 53（西安熱工研究院ﾔﾝ･ﾊﾟｵ氏）⑥

排煙処理技術について（清華大学ﾔｵ･ｷﾝ教授）······································ 54⑦

火力発電所における新しい省水技術（SPX 発電設備ｻｰﾋﾞｽ社ﾄﾑ･ﾃﾞﾝﾃﾞｨ氏） 55⑧

環境に調和した石炭火力発電（ﾀﾊﾟｰｲﾝﾀｰﾅｼｮﾅﾙ社ﾌﾞﾗｯﾄﾞ･ﾗﾄﾞﾙ氏） ············· 55⑨乾式冷却方式の水凝縮精製に伴う問題点と解決 ···································· 56（西安熱工研究院ﾃｨｱﾝ･ｳｪｲﾊ博士）(9) 第 8 セッション「FBC/USC/IGCC/CCS」 ·················································· 57①

CSIRO における燃焼後 CO2 回収について（CSIRO ﾎﾟｰﾙ･ﾌｪﾛﾝ博士） ······· 57②

乾式給炭二段噴床石炭ｶﾞｽ化炉の開発（西安熱工研究院ｼｭｰ･ｼｾﾝ博士） ······· 58③低品位炭を使った流動床ﾎﾞｲﾗ技術（JPOWER 西江④

中国における超々臨界発電技術の現状（西安熱工研究院ｿﾞｵ･ﾊﾟｵﾃｨｱﾝ氏）··· 59⑤

韓国における 3t/d 石炭ｶﾞｽ化ｼｽﾃﾑの解析（亜州大学ﾋｭﾝ･ﾃｸ･ｷﾑ教授） ········· 60⑥

APEC 諸国に炭素固定化技術ﾌﾟﾟﾛｼﾞｪｸﾄ ·············································· 61義輝氏）··············· 59（ｶﾅﾀﾞ天然資源総局ﾌﾗﾝｸ･ﾓｰﾘｽ博士）⑦

中国における GE のｶﾞｽ化・IGCC 技術（GE ｴﾈﾙｷﾞｰ社ｼﾞｬﾝﾌｪﾝ･ﾙｲ氏）······· 62⑧酸素燃焼発電所からの CO2 回収 FS と燃焼試験結果 ····························· 63（IHI 橋本敬一郎氏）⑨(10)

国産 CFB ﾎﾞｲﾗ技術（西安熱工研究院ｽﾝ･ｼｱﾝﾋﾞﾝ氏） ······························ 64
第 9 セッション「排煙処理技術」 ·························································· 65

①中国の石炭火力発電所における選択接触還元脱硝技術適用問題 ················ 65（中国国立燃焼技術ｾﾝﾀｰ

ﾜﾝ･ﾕﾐﾝ氏）②

蒸気ﾌﾟﾗﾝﾄの排出削減と効率向上（SPX 発電設備ｻｰﾋﾞｽ社ﾄﾑ･ﾃﾞﾝﾃﾞｨ氏） ····· 66③

活性炭素繊維を用いた高効率 SO2 除去技術········································· 67（ｴﾈﾙｷﾞｰ･鉱物資源省ﾐﾌｧﾀﾌﾙ･ﾌﾀﾞ博士）④

石炭火力発電所における SCR の技術選択（西安熱工研究院ｿﾞﾝ･ｷﾝ博士） ·· 68⑤

ｴｱﾓﾆﾀｰ社の通風計測技術をなぜ選択するのか（ｴｱﾓﾆﾀｰ社ﾃﾞｨﾋﾞｯﾄ･ﾀﾞﾑ氏）··· 69(11) 第 10 セッション「発電所の自動化・情報化技術」 ···································· 69①

ﾌﾟﾗﾝﾄﾚﾍﾞﾙにおける情報管理ｼｽﾃﾑとその開発 ········································ 69（西安熱工研究院ﾔﾝ･ﾄﾞﾝ氏）②

発電技術における新技術開発と機器管理の情報化 ································· 70（華能集団公司ｻﾞｵ･ｼﾞﾝﾄﾞﾝ氏）③

華能国際電力における燃料支払い管理ｼｽﾃﾑ ·········································· 71（華能国際電力公司ｻﾞｵ･ｱﾝｼｪﾝ氏）④ ﾃﾞｼﾞﾀﾙ発電所の基礎～ﾌｨｰﾙﾄﾞﾊﾞｽ･ｺﾝﾄﾛｰﾙ･ｼｽﾃﾑ ······································ 71（西安熱工研究院ﾔﾝ･ﾕﾋﾟﾝ氏）(11) 閉会セッション ·················································································· 72①

ｾﾐﾅｰｻﾏﾘｰ（西安熱工研究院院長・中国電力ｴﾝｼﾞﾆｱﾘﾝｸﾞ学会火力発電部会事務局長
ｼﾞｬﾝ･ﾐﾝﾊ氏） ················································································ 72②

閉会の辞（APEC EGCFE 議長 Mr. Scott Smouse） ····························· 73

3.

需給予測結果取纏め ·············································································· 75

4.

テクニカルツアー ················································································· 84

【資

料 集】

1.

セミナープログラム ·············································································· 882.

講演資料 ····························································································· 94(1) 開会セッション····················································································· 94⑥ 開会挨拶 1（中国電力ｴﾝｼﾞﾆｱﾘﾝｸﾞ学会副会長 ｼﾞｬﾝ･ｷﾞｼﾝ氏） ···················· 95⑦ 開会挨拶 2（APEC EGCFE 議長ｽｺｯﾄ･ｽﾏｳｽ氏） ···································· 102⑧ 基調講演 1（科学技術省副局長ｼｭｰ･ｼﾞｬﾝ氏）········································· 109⑨ 基調講演 2（JAPAC 副会長・JCOAL 理事長 安藤 勝良博士）·············· 113⑩ 基調講演 3（中国華能集団公司副社長ｳｰ･ﾙｵｼ氏）··································· 149(2) 第 1 セッション「石炭の需給予測 1」 ························································ 155④ 中国の石炭産業開発の政策の方向性（中国煤炭協会 ｼﾞｬﾝ･ﾖﾝ氏） ·············· 156⑤ ﾏﾚｰｼｱにおける石炭需給予測（TNB 燃料公社 ﾋｭｰ・ﾁｬｰ・ﾛﾝ氏） ··············· 160

⑥ ﾀｲにおける石炭需給予測（ｴﾈﾙｷﾞｰ省ｴﾈﾙｷﾞｰ政策計画庁ｻﾏﾙｼﾞｬｲ･ｽｸｽﾒｸ氏） ··· 186(3) 第 2 セッション「クリーンな石炭火力発電所」············································ 208⑤ 中国における石炭火力発電所の開発と現状（中国工程院ﾌｧﾝ･ﾁﾘ氏） ··········· 209⑥ 世界規模な気候変動緩和に係る技術の役割 ··········································· 257（米国環境保護庁ﾌﾗﾝｸ･ﾌﾟﾘﾝｼｵｯﾀ氏）⑦ ｸﾞﾘｰﾝｼﾞｪﾝ技術（中国華能集団公司ﾌｰ･ｼﾊｲ氏） ······································ 290(4) 第 3 セッション「クリーンな石炭火力発電所」············································ 323①

APEC 途上国においての CCT を促進するための環境規制の導入理由 ········ 324（米 SAIC ｼﾞｪｯﾄ･ﾌｪﾝﾃﾞｿﾝ氏）②

中国初国産 300MW 流動床ﾎﾞｲﾗ-について（中国大唐集団公司ｼﾞﾝ･ﾊｵﾊ氏）· 343③

CCT を用いた石炭火力発電所（韓国電力公社ｽﾝﾁｭﾙ･ｷﾑ博士）··············· 377(5) 第 4 セッション「石炭需給予測 2」··························································· 416①

ﾌｨﾘﾋﾟﾝにおける石炭需給予測（ｴﾈﾙｷﾞｰ省ﾚｽﾄｳﾄ･ﾀﾅｶﾞｽ氏） ······················· 417②

ｲﾝﾄﾞにおける石炭需給予測（石炭省 KS ｸﾛﾌｧ氏）·································· 437③

韓国における石炭需給予測（韓国石炭公社ｼﾞｪｴﾎ･ｷﾑ博士）······················ 466④

台湾における石炭需給予測（経済部ｼﾞｪﾝｼｪﾝ･ｽｰ氏） ······························ 488⑤日本の石炭政策（資源ｴﾈﾙｷﾞｰ庁 近藤 裕之氏） ··································· 508(6) 第 5 セッション「クリーンな石炭火力発電所」············································ 531①

環境保全技術の現状と石炭火力発電所の開発 ······································· 532（中国国電集団公司ﾜﾝ･ｿﾞﾝｸﾞ氏）②

石炭火力発電所における省ｴﾈﾙｷﾞｰ（中国電力投資社ｼﾞﾝ･ﾄﾞﾝｸﾞﾚ氏） ·········· 559③

先進的ﾊﾟﾗﾒｰﾀｰを持った石炭火力発電所の省ｴﾈﾙｷﾞｰ開発 ·························· 591（中国貨能国際電力有限公司ﾙｰ･ｸﾞｵｴ氏）(7) 第 6 セッション「石炭供給展望」 ····························································· 611①

中国における石炭需給と石炭産業政策（中国煤炭販売輸送協会ﾙｰ･ｼｬｵﾔﾝ氏）612②

豪州における石炭供給展望（産業観光資源省 ﾙｲｽ･ﾀﾏｼｭｹ氏）··················· 616③

ｲﾝﾄﾞﾈｼｱにおける石炭供給展望（ｴﾈﾙｷﾞｰ･鉱物資源省ｽｸﾏ･ﾊｼﾊﾞｰﾝ博士） ······· 635④

ﾛｼｱにおける石炭供給展望（ﾛｼｱ科学ｱｶﾃﾞﾐｰｼﾍﾞﾘｱ支部ﾄﾞﾐﾄﾘｰ･ｿｺﾛﾌ氏） ······· 656⑤

ﾍﾞﾄﾅﾑにおける石炭供給展望（VINACOMIN ｷｭｰ･ｷﾑ･ﾁｪｸ博士） ··············· 675⑥

ｲﾝﾄﾞﾈｼｱの石炭開発（ｴﾈﾙｷﾞｰ･鉱物資源省ﾊｼﾞ･ﾇｻﾙﾔ博士）························· 720(8) 第 7 セッション「石炭火力発電所における省ｴﾈ・省水」 ································ 741①

低温海水淡水か適用と発電と水の生産（北京国貨有限公司ｼﾞｬﾝ･ｼﾞｬﾝｸﾞﾘ氏）742②

ｴﾈﾙｷﾞｰ効率向上と低公害のための低ﾘｽｸ高ﾘﾀｰﾝの TIFI tm 技術ローﾘｽｸ ········ 764（ﾌｭｴﾙﾃｯｸ社ﾘﾝﾀﾞ･ﾘﾝ博士）③

石炭火力発電所のｴﾈﾙｷﾞｰ消費評価と省ｴﾈﾙｷﾞｰ可能性解析························· 812（西安熱工研究院ﾕｰ･ｼﾝﾕﾝ氏）④

石炭火力発電所のﾘﾉﾍﾞｰｼｮﾝ（JCOAL 竹川 東明氏）···························· 876⑤中国の石炭火力発電所における省水技術の現状（西安熱工研究院ﾔﾝ･ﾊﾟｵ氏）899⑥

排煙処理技術について（清華大学ﾔｵ･ｷﾝ教授）······································ 915

⑦

火力発電所における新しい省水技術（SPX 発電設備ｻｰﾋﾞｽ社ﾄﾑ･ﾃﾞﾝﾃﾞｨ氏） 966⑧

環境に調和した石炭火力発電（ﾀﾊﾟｰｲﾝﾀｰﾅｼｮﾅﾙ社ﾌﾞﾗｯﾄﾞ･ﾗﾄﾞﾙ氏） ············· 982⑨

乾式冷却方式の水凝縮精製に伴う問題点と解決 ···································· 1012
（西安熱工研究院ﾃｨｱﾝ･ｳｪｲﾊ博士）(9) 第 8 セッション「FBC/USC/IGCC/CCS」 ·················································· 1044①

CSIRO における燃焼後 CO2 回収について（CSIRO ﾎﾟｰﾙ･ﾌｪﾛﾝ博士） ······· 1045②

乾式給炭二段噴床石炭ｶﾞｽ化炉の開発（西安熱工研究院ｼｭｰ･ｼｾﾝ博士） ······· 1075③低品位炭を使った流動床ﾎﾞｲﾗ技術（JPOWER 西江 義輝氏）··············· 1113④

中国における超々臨界発電技術の現状（西安熱工研究院ｿﾞｵ･ﾊﾟｵﾃｨｱﾝ氏）··· 1129⑤

韓国における 3t/d 石炭ｶﾞｽ化ｼｽﾃﾑの解析（亜州大学ﾋｭﾝ･ﾃｸ･ｷﾑ教授） ········· 1182⑥

APEC 諸国に炭素固定化技術ﾌﾟﾟﾛｼﾞｪｸﾄ（ｶﾅﾀﾞ天然資源総局ﾌﾗﾝｸ･ﾓｰﾘｽ博士）1222⑦

中国における GE のｶﾞｽ化・IGCC 技術（GE ｴﾈﾙｷﾞｰ社ｼﾞｬﾝﾌｪﾝ･ﾙｲ氏）······· 1250⑧

酸素燃焼発電所からの CO2 回収 FS と燃焼試験結果（IHI 橋本⑨

国産 CFB ﾎﾞｲﾗ技術（西安熱工研究院ｽﾝ･ｼｱﾝﾋﾞﾝ氏） ······························ 1302⑩

T91-F12 型鉄鋼の異種金属溶液の研究 ··············································· 1330

(10)敬一郎氏）1279

第 9 セッション「排煙処理技術」 ·························································· 1370①中国の石炭火力発電所における選択接触還元脱硝技術適用問題 ················ 1371
（中国国立燃焼技術ｾﾝﾀｰ

ﾜﾝ･ﾕﾐﾝ氏）②

蒸気ﾌﾟﾗﾝﾄの排出削減と効率向上（SPX 発電設備ｻｰﾋﾞｽ社ﾄﾑ･ﾃﾞﾝﾃﾞｨ氏）······ 1398③

活性炭素繊維を用いた高効率 SO2 除去技術 ········································· 1421
（ｴﾈﾙｷﾞｰ･鉱物資源省ﾐﾌｧﾀﾌﾙ･ﾌﾀﾞ博士）④

石炭火力発電所における SCR の技術選択（西安熱工研究院ｿﾞﾝ･ｷﾝ博士） ··· 1445⑤

ｴｱﾓﾆﾀｰ社の通風計測技術をなぜ選択するのか（ｴｱﾓﾆﾀｰ社ﾃﾞｨﾋﾞｯﾄ･ﾀﾞﾑ氏） ··· 1480

(11) 第 10 セッション「発電所の自動化・情報化技術」 ···································· 1523①

ﾌﾟﾗﾝﾄﾚﾍﾞﾙにおける情報管理ｼｽﾃﾑとその開発（西安熱工研究院ﾔﾝ･ﾄﾞﾝ氏） ··· 1524②

発電技術における新技術開発と機器管理の情報化 ·································· 1576
（華能集団公司ｻﾞｵ･ｼﾞﾝﾄﾞﾝ氏）③

華能国際電力における燃料支払い管理ｼｽﾃﾑ（華能国際電力公司ｻﾞｵ･ｱﾝｼｪﾝ氏）1630④

ﾃﾞｼﾞﾀﾙ発電所の基礎～ﾌｨｰﾙﾄﾞﾊﾞｽ･ｺﾝﾄﾛｰﾙ･ｼｽﾃﾑ ······································ 1635
（西安熱工研究院ﾔﾝ･ﾕﾋﾟﾝ氏）(12) 閉会セッション ·················································································· 1668①

ｾﾐﾅｰｻﾏﾘｰ（西安熱工研究院院長・中国電力ｴﾝｼﾞﾆｱﾘﾝｸﾞ学会火力発電部会事務局長
ｼﾞｬﾝ･ﾐﾝﾊ氏） ················································································ 1669②

閉会の辞（APEC EGCFE 議長 Mr. Scott Smouse） ····························· 1670

【本

編】

１．

要 約
開催意義および成果

1.

将来にわたる石炭の安定的な確保は我が国にとって重要な課題であるが、アジア太平洋地域においては中長期的に石炭需要の大幅な増加が予見されている。
本セミナーは、日本の主唱により平成 6 年度に APEC コールフローセミナーとして第 1 回が開催されて以来、域内の主要な生産及び消費国･地域の官民石炭関係者を集め、石炭に係る現状や課題等について情報交換を行い共通認識の形成を図ることを目的として、毎年開催されてきた。
第 14 回となる今回は、日本国経済産業省、中国電力エンジニアリング学会火力発電分会(TPC/CSEE)、及び米国エネルギー省の主催により、APEC エネルギー作業部会（EWG）クリー
ン化石エネルギー専門家グループ（EGCFE）の事業として従来同様 APEC 事業である第 15 回ア
ジア太平洋クリーン化石エネルギー技術セミナーと合同にて、且つ、中国の電力エンジニアリング
学会年次大会を合わせて行う形で、「Harmonious and Sustainable Coal Power Generation」とのテーマのもとに開催された。
本セミナーは、著しい経済成長により今後の地球環境問題と石炭需給動向の鍵を握る中国で開催された。現在、石炭は環境と需給の両面でかつてなく厳しい状況に置かれており、今後中国・インドをはじめアジア各国の急速な成長に伴ってこの厳しさは確実に増していくと思われる。先般のハイリゲンダムサミットで CO2 削減について世界に新たな提案を行い、一方でエネルギーの資源の大部分を海外に頼っている日本としては、クリーン・コール・テクノロジーの開発とアジア各国への普及を加速して、限りある石炭資源のより効率的な利用に貢献し、ひいては我が国への石炭の安定供給を確保することが非常に重要であると思料される。そのためにも各国関係者が共通認識を持
ち、協調していくことの重要性を改めて感じさせるセミナーであった。

2.

開催日時： 平成 19 年 10 月 15 日（月）～10 月 17 日（水）3.

開催場所： 中国西安市 陝西丈八溝賓館

4. 主催及び後援：
主催
APEC 化石エネルギー専門家会合（EGCFE）
中国電力エンジニアリング学会火力発電部会（TPC/CSEE）
運営委員会
日本国経済産業省（METI）
中国電力エンジニアリング学会火力発電部会（TPC/CSEE）
米国エネルギー省（DOE）
開催機関
西安熱工研究院（TPRI）
後援
独立行政法人新エネルギー･産業技術総合開発機構（NEDO）

太平洋コールフロー推進委員会（JAPAC）(財団法人石炭エネルギーセンター内)
中国華能集団公司・中国大唐公司・中国華電公司・中国国電公司・中国電力投資公司
中国石炭工業協会（CNCA）
米国エネルギー省エネルギー技術研究所（NETL）

5.

参加者

(1) 参加者数：
参加国･地域：

計約 220 名
中国、日本、米国、豪州、インドネシア、ロシア、ベトナム、韓国、台湾、
タイ、マレーシア、フィリピン、カナダ、インド（計 14 カ国･地域）

6.

概要

開会セッション
議長：

ジャン・ミンハ氏
中国西安熱工研究院院長
中国電力エンジニアリング学会火力発電部会事務局長

開会挨拶 1：

ジャン・ギシン氏
中国電力エンジニアリング学会副理事長

開会挨拶 1：

スコット･スマウス氏
APEC EGCFE（化石燃料部会）議長

基調講演 1：

シュー・ジャン氏
中国科学技術省（MOST）開発計画局 副局長

基調講演 2：

安藤 勝良氏
太平洋コールフロー推進委員会（JAPAC）副会長
財団法人石炭エネルギーセンター（JCOAL）理事長

基調講演 3：

ウー・ルオシ氏
中国華能集団公司 副社長

第 1 セッション（石炭需要予測 1）
議長：

近藤 裕之氏
経済産業省（METI）資源エネルギー庁（ANRE）
資源・燃料部 石炭課課長補佐

講演者1：

ジャン・ヨン氏
中国煤炭工業協会(CNCA)政策研究部副部長「中国の石炭産業開発の政策の方向性」

講演者2：

ヒュー・チャー・ロン氏
マレーシア国TNB燃料公社上級職（ロジ担当）「マレーシアにおける石炭需要予測」

講演者3：

サマルジャイ・スクスメク氏
タイ国エネルギー省エネルギー政策計画庁（EPPO）
エネルギー政策計画部長

「タイにおける石炭需要予測」
第 2 セッション（クリーンな石炭発電技術）
議長：

ジャン・ミンハ氏
中国西安熱工研究院院長
中国電力エンジニアリング学会 事務局長

講演者1：

フアン・チリ氏
中国工程院 工程師 （中国）
「中国における石炭火力発電所の開発と現状

講演者2：

フランク・プリンシオッタ氏
米国環境保護庁(EPA) 大気汚染防止・管理部長「世界規模な気候変動緩和に係る技術の役割」

講演者3：

フー・シハイ氏
中国華能集団公司 部長補佐
「GreenGen プロジェクト」

第 3 セッション（クリーンな石炭発電技術）
議長：

フアン・チリ氏
中国工程院 工程師

講演者1：

ジェット・フェンデソン氏
米国 SAIC サイエンス・アプリケーションズ・インターナショナル・コーポレーション 気候変動部 プログラム担当副部長「APEC 内発展途上国においての CCT を促進するための環境規制の導
入理由」

講演者2：

ジン・ヤオハ 氏
中国大唐集団公司 副主任エンジニア「中国初国産 300MW 流動床ボイラーについて」

講演者3：

スンチュル・キム博士
韓国電力公社(KEPCO) 燃焼発電技術グループ グループ長「CCT を用いた石炭火力発電所」

第 4 セッション（石炭需要予測 2）
議長：

ルイス・タマシュケ氏
産業観光資源省 資源部 石炭政策課 課長補佐

講演者1：

レストウト・タガナス氏
フィリピン国エネルギー省 エネルギー資源開発局担当副部長「フィリピンにおける石炭需要展望」

講演者2：

KS・クロファ氏
インド国石炭省 次官補「インドにおける石炭需要展望」

講演者3：

ジャエホ・キム博士
韓国石炭公社(KOCOAL) 技術調査研究所 所長「韓国における石炭需要展望」

講演者4：

ジンシェン・スー氏
台湾経済部 能源部 電力部長
「台湾における石炭需要展望」

講演5：

近藤 裕之氏
日本国経済産業省 資源エネルギー庁 資源燃料部石炭課課長補佐「日本の石炭政策」

第 5 セッション（クリーンな石炭発電技術）
議長：

ニー・ウェイドゥ氏
中国工務院 工程師

講演者1：

ワン・ゾング氏
中国国電集団公司 保安管理部 部長「環境保全技術の現状と石炭火力発電所の開発」

講演者2：

ジン・ドングレ氏
中国電力投資社 保安管理部副部長「石炭火力発電所における省エネ」

講演者3：

ルー・グオエ氏
中国貨能国際電力有限公司 副部長「先進的高パラーメーターを持った石炭火力発電所の省エネルギー開発」

第 6 セッション（石炭供給予測）
議長：

レストウト・タガナス氏
フィリピン国エネルギー省 エネルギー資源開発局 担当部長

講演者1：

ルー・シャオヤン氏
中国煤炭販売輸送協会 情報センター 研究諮詢部部長（著者；中国煤炭販売輸送協会 情報センター 副所長 ハオ・シャンビン氏）

講演者 2：

ルイス・タマシュケ氏
豪州産業観光資源省 資源部石炭政策課 課長補佐
「豪州における石炭供給展望」

講演者3：

スクマ・ハシバーン博士
インドネシア国エネルギー・鉱物資源省 鉱物・石炭・地熱管理局部長「インドネシアにおける石炭供給展望」

議長：

ヒュー・チャー・ロン氏
マレーシア国TNB燃料公社 上級職（ロジ担当）

講演者4：

ドミトリー・ソコロフ氏
ロシア連邦ロシア科学アカデミーシベリア支部 エネルギーシステム研究所から出向
韓国エネルギー研究所 北東アジアエネルギー研究センター
国際研究員
共著；ロシア科学アカデミーシベリア支部 エネルギーシステム研究所副所長 ボリス・サネーフ教授・同研究所ラボ担当部長 アレキサンダー・ソ
コロフ教授「ロシアにおける石炭供給展望」
講演者5：

キュー・キム・チョク博士
ベトナム VINACOMIN グループ 鉱山科学技術研究所 国際部課長「ベトナムにおける石炭供給展望」

講演者6：

ハジ・ヌサルヤ博士
インドネシア国エネルギー・鉱物資源省 調査開発庁部長 調整部部長「インドネシアの石炭開発」

第 7 セッション（石炭火力発電所における省エネ・省水）
議長：

ザオ・イー氏
中国西安熱工研究院 副院長

講演者1：

ジャン・ジャングリ氏
中国北京国貨有限公司 上級技師
共著；北京国貨有限公司 副主任技師 チェン・ユンビオ氏「低温海水淡水化適用と発電と水の生産」

講演者2：

リンダ・リン博士
米国フュエルテック社 アジア太平洋地区 担当副社長「エネルギー効率向上と低公害のための低リスク高リターンのTIFItm技
術」

講演者3：

ユー・シンユン氏
中国西安熱工研究院 公益事業技術部 副部長「石炭火力発電所のエネルギー消費評価と省エネルギー可能性解析」

講演者4：

竹川 東明博士
日本国財団法人石炭エネルギーセンター 事業化推進部長
共著；中電連 ルー・ユシェン氏・ハオ・ジホン氏「石炭火力発電所のリノベーション」

講演者5：

ヤン・バオ氏
中国西安熱工研究院 水力技術部 部長「中国の石炭火力発電所における省水技術の現状」

議長：

スン・ルイ氏中国中国電力工程顧問集団公司 主幹技師

講演者6：

ヤオ・キン教授
中国清華大学 発電技術部 部長
国立国内炭専用産業ボイラ・燃焼技術研究所 部長「排煙処理技術について」

講演者7：

トム・デンティ氏
米国 SPX 発電設備サービス社 世界市場開発部 部長「火力発電所における新しい省水技術」

講演者8：

ブラッド・ラドル氏

米国タバーインターナショナル社 社長兼技監「環境に調和した石炭火力発電」
講演者9：

ティアン・ウェイハ博士
中国西安熱工研究院「乾式冷却方式の水凝縮精製に係る問題点と解決」

第 8 セッション（FBC/ USC/IGCC/ CCS）
議長：

ヤオ・キン教授
中国清華大学 発電技術部 部長・ 国立国内炭専用産業ボイラ・燃焼技術研究所 部長

講演者 1：

ポール・フェロン博士
豪州 CSIRO エネルギー研究所 科学担当 CEO「CSIRO における燃焼後 CO2 回収について」

講演者 2：

シュー・シセン博士
中国西安熱工研究院 主幹技師
「乾式給炭二段噴流床石炭ガス化炉の開発」

講演者 3：

西江 嘉晃氏
日本国電源開発㈱ 国際事業部調査役（副部長）「低品位炭を使った流動床ボイラ技術」

講演者 4：

ゾオ・バオティアン氏
中国西安熱工研究院 主幹技師
「中国における超々臨界発電技術の現状」

講演者 5：

ヒュン・テク・キム博士
韓国亜州大学 エネルギーシステム部教授「韓国における 3t/d 石炭ガス化システムの解析」

議長：

シヒュン・リー博士
韓国韓国エネルギー研究所(KIER) エネルギーシステム研究センター
エネルギー転換研究部 研究主幹

講演者 6：

フランク・モーリツ博士
カナダ天然資源総局 エネルギー研究室上級科学技術アドバイザー「APEC 諸国における炭素固定化技術プロジェクト」

講演者 7：

ジャンフェン・ルイ氏
米国 GE エネルギー社 中国支社 技術開発部 技術担当部長「中国における GE のガス化・IGCC 技術」

講演者 8：

橋本 敬一郎氏㈱IHI 電力事業部開発部 主査「酸素燃焼発電所からのCO2回収FSと燃焼試験結果」

講演者 9：

スン・シアンビン氏
中国中国熱工研究院 CFB ボイラ技術部 主任科学者 主任技師
「国産 CFB ボイラ技術」

第 9 セッション（排煙処理技術）
議長：

フランク・モーリツ博士
カナダ天然資源総局 エネルギー研究室上級科学技術アドバイザー

講演者 1：

ワン・ユミン氏
中国国立石炭燃焼技術センター センター長「中国の石炭火力発電所における選択接触還元脱硝技術適用問題」

講演者2：

トム・デンティ氏
米国 SPX 発電設備サービス社 世界市場開発部 部長「蒸気プラントの排出削減と効率向上」

講演者 3：

ミファタフル・フダ博士
インドネシア国エネルギー・鉱物資源省 エネルギー鉱物資源研究所
主幹研究員「活性炭素繊維を用いた高効率 SO2 除去技術」

講演者 4：

ゾン・キン博士
中国西安熱工研究院 SCR グループ グループ長「石炭火力発電所における SCR の技術選択」

講演者 5：

ディビット・ダム氏
米国エアモニター社 アジア太平洋販売部長 氏「Air Monitor 社の通風計測技術をなぜ選択するか？」

第 10 セッション（発電所の自動化・情報化技術）議長：

リュー・ウェイ氏
中国西安熱工研究院 副院長

講演者1：

ヤン・ドン氏
中国西安熱工研究院 ソフトウエア管理部門 発電課 次長「プラントレベルにおける情報管理システムとその開発」

講演者2：

ザオ・ジンドン氏
中国華能威海発電所 副部長「発電所における新技術開発と機器管理の情報化」

講演者3：

ザオ・アンシェン氏
中国華能国際電力公司「華能国際電力における燃料支払い管理システム」

講演者4：

ヤン・ユピン氏
中国西安熱工研究院 フィールドバスコントロール技術部
主幹技師「デジタル発電所の基礎～フィールドバス・コントロール・システム(FCS)」

閉会セッション
セミナーサマリー：

ジャン・ミンハ氏
中国西安熱工研究院 院長
中国電力エンジニアリング学会 事務局長

閉会挨拶：

スコット･スマウス氏

APEC EGCFE 議長
米国エネルギー省国立エネルギー技術研究所国際協力チーム長7.

テクニカル･ツアー

10月17日（水）、セミナー参加者のうち約20名により、西安市郊外の渭河（Wei-He）発電所の見学を行った。

8. 歓迎会等
ホスト国である中国西安熱工研究院が、セミナー関係者を集め歓迎会を開催した。

2. 講演概要① 開会セッション Opening Session
議長：Mr. Jiang Minhu, Director of TPC/CSEE, President of TPRI (PR China)
中国電力エンジニア学会 火力発電部会 事務局長・西安熱工研究院 院長
ジャン・ミンハ氏（中国）
開会挨拶 1
Mr. Zhang Guixing, Vice President of CSEE
電力エンジニアリング学会 副理事長 ジャン・ギシン氏（中国）今回セミナーの Host Organizer の責任者を務めることとなり大変光栄に思う。まず、諸外国及び中国から、たくさんの方々に本セミナ
ーにご参加頂いたことにお礼を申し上げる。またセミナー開催準備のための協力頂いた日本、米国、中国の関係各組織の皆様にもお礼を申し上げたい。
今回「Harmonious and Sustainable Coal Power Generation」のテーマの下に APEC 各
国地域から 200 名近い専門家がここ西安に集い意見交換を行うが、石炭は発電用燃料として
APEC 地域、とりわけ中国にとって非常に重要なエネルギー資源である。
人間と自然及び人間と人間の調和は世界共通の目標であるが、今回のセミナーも、この目標達成のための努力の一環である。
環境と調和し持続的な運営が可能な石炭火力発電の実現を検討するにあたっては、石炭資源が有限であることを念頭に置くとともに、利用効率を最大限に高め、環境への負荷を最小限にとどめるための検討が重要である。
今回セミナーが調和的な雰囲気の中で行われ、成果をあげることを期待したい。

開会挨拶 2Mr. Scott Smouse, APEC EGCFE Chair (US)APEC EGCFE 議長 スコット・スマウス氏（米国）
今回セミナー開催にあたり、準備にあたった関係各位に感謝申し上げたい。各地から集まった参加者が、開催期間中に、知識と経験を共有できることを希望している。
現在世界中で石炭は、電気がどこから来るか知らない人々や石炭以外のエネルギーにどのようなリスクが伴うのかを知らない人々からの攻撃にさらされている。
最近も、米国を始め、タイ、ベトナム、豪州等で、石炭火力発電所の運転や建設への反対運

動が相次いでいる。IGCC を運転中の米国やオランダの企業でさえ批判の対象となっている。
一方、最近の米国の世論調査で、近隣に石炭火力ができることに反対する大人の割合は57％という結果が出たが、これは昨年の 74％と比べればかなり好転しており、石炭火力の必要性に米国人がやっと気づき始めたことを示している。
世界の石炭需要はアジア太平洋地域を中心に毎年増加し続けており、石炭価格を上昇させている。世界は、エネルギーが安価に安定的に供給されない脅威、エネルギーの使いすぎで有害な環境問題が生ずる脅威の二つに直面している。IEA は 2006 Energy Outlook の中で、将来のエネルギー需要に対応するには、2030 年までに総額 20 兆ドルの投資が必要と予測している。内、56％は電力分野であり、主な対象地域は、石炭に大きく依存しているアジアである。
IEA によれば、世界の石炭消費は今後 2030 年までに約 60％増加し、約 20 年の間に中国の石炭消費は 2 倍に、インドでは 1.3 倍になると予想される。世界最大の石炭生産国中国は、
昨年 23 億トンの石炭を生産したが発電用の需要を満たせず、先日の新華社の報道によれば、2010 年までに石炭産業の合理化を進め一連の超大型炭鉱を整備することにより、年間 4 億トンの増産を計画している。
多くの人が、米国や中国、インドが、CO2 を減らさねばならないにもかかわらず、なぜ非常な勢いで石炭火力発電所を作り続けるのか疑問を抱いているが、答えは、石炭火力以外に現実的な選択肢がないからである。だからといって、我々が石炭をクリーンに生産し消費する義務から免れるわけではない。石炭と CO2 の問題は一般市民にかつてない関心を呼んでおり、
子供向けパソコンゲームにおいてさえも石炭は環境に有害なエネルギーとされている。
米国政府は、クリーン・コール・テクノロジーに 30 年間で 200 億ドルを投じてきたが、今後とも官民が連携し、APP 等を通じた国際協力により最終的にゼロエミッションを目指した技術開発を進める。米国の FutureGen を始め、中国の GreenGen、日本の EAGLE、等世界各国で同様の努力が進められている。新しい技術はコストが高く信頼度が低いため、早期に商業化と普及を図るには優遇税制等のインセンティブが必要である。CO2 削減に絶大な効果を発揮
する CCS もコストが高いが 10～20 年内に妥当なレベルまでコストが下がることが期待される。
我々は今までも多くの困難な問題を克服してきたのだから、今後も残された問題を解決することは可能であると信ずる。気候変動は世界の問題で、解決は一国では不可能であり、国際協
力のみにより可能である。最近ライス国務長官が述べたように、エネルギー問題と環境問題への取組みは、気候変動が原因となって先進国と途上国の格差が更に拡大しないようにするためにも必要である。
それ故に、今回のセミナーのような場を通じ、豊かで持続的成長が可能な世界を目指して、関係各国地域がエネルギーの将来について意見を交換し、互いの問題点を理解しあい、情報と認識を共有することは非常に重要である。

基調講演1
Mr. Xu Jing, Deputy Director-General,
Department of Development Planning,
Ministry of Science & Technology (MOST)(PR China)
科学技術省(MOST) 計画開発局 副局長 シュー・ジャン氏（中国）エネルギーは人類の生存と発展にとって必要不可欠だが、現在、世界全体のエネルギー消費の約８０％が石炭・石油・天然ガス等化石燃料によるものであり、中でも石炭はアジア太平洋地域において主導的な位置を占める重要なエネルギー資源である。石炭火力発電をよりクリーンで効率の高いものとすることは、アジア太平洋地域の持続的発展のために、非常に重要な意義を有する。
現在、経済のグローバル化が非常な勢いで進んでいる一方で、経済発展と資源及び環境との間に生ずる矛盾は日増しに先鋭化しつつある。エネルギーの持続的な安定供給と地球環
境保護の両立は、世界各国共通の重要な課題である。
エネルギーと環境の矛盾の解決は、中国の科学技術政策の中でも重要なテーマであり、この課題に中国政府は早い時期から取り組んできた。中国政府は、1994 年に 21 世紀における持続可能な成長のための戦略案を策定し、1996 年にはこれを正式な国家の戦略のひとつとした他、「863 計画(ハイテク研究発展計画)」・「973 計画(国家重点基礎研究発展計画)」において、重要な課題と位置付けている。
また、第 10 次・第 11 次の 5 ヵ年計画でも重要な課題とされており、「国民経済と社会発展のための第 11 次 5 カ年計画要綱」の中には、国内生産に伴う総エネルギーロスを約 20％減らすこと、主要汚染物質の総排出量を 10％減らすことが目標として明記されている。目標達成のため、国務院は省エネ及び排出削減推進総合計画案及び国家気候変動対策案を策定し、併せて科学技術省では、それぞれに関するアクションプランを策定した。
これまでの多年に亘る努力の結果、主要工業におけるエネルギー効率等は世界の先進的レベルに近づきつつある。今年上半期の実績では、生産に伴うエネルギーロスは 2.8%改善され、SOx の排出は 0.88%減少し、COD にも改善が見られる等成果が見られたが、世界の先進的なレベルと比べればまだ大きな差があり改善への更なる努力が必要である。
石炭火力発電に関係する重点テーマには、コンバインドサイクル、ＩＧＣＣ、超々臨界、大型循
環流動床、石炭液化、ガス化、等があるが、第 11 次五ヵ年計画に伴う 2006 年と 2007 年の国
家科学技術計画では、石炭ガス化複合発電、太陽エネルギー発電、高効率風力発電、高圧送電、超臨界循環流動床、等が重点項目とされている。
中国経済が今後とも持続的に発展するためには、エネルギー構造を強化し、科学技術に力を入れ、資源節約型の環境と調和した社会の実現を目指さなければならない。
今回のセミナーは、現在の世界の動向に照らし時宜を得たものであり、これを機にエネルギーと環境に関する科学技術の国際交流と国際協力が活発に行われることを希望する。

基調講演2JAPAC 副会長・JCOAL 理事長 安藤勝良博士
石炭は、現在、環境と資源の両面で、かつてないほど緊迫した状況に置かれている。
2007 年 5 月に国連気候変動に関する政府間パネル(IPCC)がまとめた地球温暖化緩和策の報告書は、気温上昇を影響の少ない 2 度程度に抑えるには世界の温室効果ガスの排出量を 2020 年までに減少に転じさせ 2050 年には 2000 年に比べ半減させる必要があると指摘。6 月のハイリゲン
ダムサミットでは日本の安倍総理が「美しい星へのいざない～Invitation to ’Cool Earth50’」により CO2 年間排出量を 2050 年に現状の半分にする目標を世界に提案し 2008 年 7
月の洞爺湖サミットに向けて引き続き検討が行われている。他にも大量排出国米国が AP6 で提唱した Future Gen が具体化に向けて動き出し、排出量増加中の中国も｢2020 年までに省
エネ 20%｣の目標を発表した。
京都議定書は地球温暖化対策の第一歩として重要だが、削減義務のある先進国の CO2 削
減は全排出量の約 3 割にとどまり効果には限界がある。今後削減義務を負わない国の排出量が急増することは必至で、総排出量は約 4 割増加すると予想される。実効ある地球温暖化防止のためには、最大排出国の米国、排出量の増加が著しい中国、インド等途上国のコミット
メントが必要である。
CO2 削減を達成するためには、各国は、自主的に産業・民生両面において徹底した削減目
標を立て「省エネルギー対策」を具体化すべきである。日本としては日本の提案に応える途上
国支援のための資金メカニズムを構築し、エネルギー効率向上に関する東アジアの取組みを世界に拡大する用意がある。
CO2 削減目標達成は不可能と主張する者は多いが、まず大胆な技術革新によるブレーク･ス
ルーと諸技術の複合化を急ぐべきである。世界の CO2 排出量の約 3 割を石炭火力が占めているが、発電電力量構成でみると世界の約 4 割が石炭火力で、米国や中国では 8 割という高率であり、年率 3%の伸びを示してきた。世界の一次エネルギーに占める石炭の割合は過去25%程度であったが、26～27%と上がってきており、最近の石炭火力へのシフト状況からすると比率はさらに大幅に上がっていると思われる。
エネルギー効率を 1%上げると CO2 は 2.5%下がるとされており、火力発電では効率向上が必須の課題である。日本では、SC、USC の実用化により 1980 年から 2005 年にかけ石炭火力
発電効率(発電端)2.5%向上し、平均約 42%と世界最高水準に達した。この間石炭火力発電所からの SOx、NOx の排出量を極端に少なくする技術も保有するに至った。今世界が競って開発している石炭ガス複合発電（IGCC）、更に A-IGCC、A-USC、A-IGFC の開発により飛躍的な改革が可能になれば CO2 の 30%削減も夢ではない。
但し発電効率向上のみでは CO2 大幅削減達成は困難であるため、化石燃料からの CO2 を大量に分離・貯留する炭素隔離技術（CCS）に国際的レベルで英知を結集すべきである。CCSは｢分離・回収、輸送、貯留｣の一貫システムにより成立するもので、総合的な取組みが必要である。｢発電効率の向上｣、｢CCS｣、「バイオとの混焼」等あらゆる技術の複合的な導入が石炭のゼロ・エミッション実現の鍵を握っている。
一方、世界の持続的好景気を反映して全ての資源の需給がタイト化し価格が急騰している。
石炭も 2003 年頃から価格上昇をみていたが、需要家側には「石炭はいつでも容易に入手できる」という安心感がありいずれ需給は緩和されると思っていたのではないか。今日の石炭価
格高騰の要因は、あまりに大きい世界的需要増に供給が追いつけないことにある。需要側の問題点としては、確固とした信念が不足し発信が甘く不確実であったことがあげられる。かつて需給がタイト化した時、供給源分散化のために需要家側がアメリカ炭・カナダ炭導入に伴い現地に港湾まで建設したにもかかわらず、需給の緩和とともに容易に撤退してしまったことに見られるように、長期的な資源論の見方が欠けていたのではなかろうか。一方、供給側についてみると長期的な需給予測があまりにもお粗末であったことを指摘せざるを得ない。
また、最近従来の価格周期説とは異なるが「石炭ピーク論・枯渇論、資源ナショナリズム台頭論」等が容易に流布しているのは大変遺憾である。これらが、地球温暖化問題に伴う石炭使用抑制・石炭離れの動きに拍車をかけかねず、更に、相当手当てが遅れていると思われるイ
ンフラの先行整備にも支障をきたしかねない、と危惧する。
石炭供給安定化のためには、有限である石炭資源の無駄な採掘（低回収率）を改善し、良質炭の選択的採掘等について反省すべき点は反省し轍を踏むことのないよう努力することが必要である。むしろ、回収率向上、低品位炭の活用、廃棄物の資源化、等により、石炭の持っているポテンシャルをいかに有効に拡大し、高度利用拡大につなげるかががポイントではなかろうか。
今日の石炭に課せられた課題に対応するには、コールチェーン全体でとらえるべきであり、｢資源｣、「利用」、「環境」の三点の調和・一体化が大事である。そのためにも、石炭関係者が情報を共有し、共通の認識を持って相互信頼を醸成することが重要である。最後に、焦眉の急である地球温暖化問題に対応するには、「省エネ」・「省資源」に徹するためのあくなき“挑戦”が重要であることを強調したい。

基調講演3
Mr. Wu Ruosi, Vice President, China Huaneng Group(PR China)
中国華能集団公司 副社長 ウー・ルオシ氏(中国)中国において石炭は、特に発電用燃料として極めて重要であり、今後ともその地位は不変である。華能集団を例にとれば、2006 年末の総発電設備容量 5,718.5 万ｋW（中国全体の約 9%に相当）の90%以上が石炭火力発電所となっている。

発電の効率を向上させ環境への影響を低減することは、電力産業の健全な発展と社会経済の持続的発展のために必要不可欠である。
華能集団公司は、中国の有力な電力企業としてクリーンで調和のとれたより良い速やかな発展を堅持し、社会のニーズに応え信頼が高く環境と調和した経済性のある電力を提供するよ
う努力しているが、石炭火力発電においてよりクリーンでより効率の高いものを目指すという路線は不動である。
華能集団公司は、超々臨界発電、GreenGen 計画、CO2 回収につき以下を実施中である。
超々臨界発電は、石炭のロスが少なく効率が高く、環境に関する性能が良好なので、世界の石炭火力が目指す方向に沿った技術である。華能集団は中国における超々臨界発電の研究開発と応用を中心となって推進しており、玉環発電所で国産初の 100 万ｋW 超々臨界発電
設備の運転に成功し 4 台が稼動している。熱効率は 45%、石炭消費は 288.5g/kWh で中国
国内平均値に比べ 70g/kWh 以上低い。また中国初の二重膜法による国内最大規模の海水淡水化を実施し年間 800 万㎥の節水を行っている。玉環発電所での実績は、中国の電力産
業史上の記念碑的成果である。また、営口発電所では国産初の 60 万 kW の超々臨界発電
設備の運転に成功した。石炭消費は 292g/kWh で中国国内平均値に比べ約 70g/kWh 低く、同規模の超臨界設備に比べ年間 14 万トンの石炭の節約、年間 2572 トンの SO2 の削減、年間 130 万トンの節水が可能である。
GreenGen 計画は、華能集団が 2005 年に提案したもので、石炭ガス化・水素製造、水素発電（水素燃焼、水素タービンと燃料電池の複合）、CO2 回収隔離貯蔵の統合システムによりニア・ゼロエミッションの実現を目指す計画である。技術開発と実証をめざし、当面は 2009 年までに 25 万ｋW の IGCC のモデルプラントを建設することを目標とする。
また、華能集団は、豪州の CSIRO と協力し、年間 3,000 トンの CO2 を回収する中国初のCCS モデルプラントを 2008 年の北京オリンピック前までに北京発電所内に建設することを決め、「北京温室効果ガス回収・処理実験室」を設置して計画を推進している。
この他華能集団は全グループを挙げて、世界の先進的なレベルに追いつき省エネ・環境保
全型の石炭火力発電を実現することを目指している。また、新設火力とは別に、老朽火力については性能の調査・分析を行い発電の効率を向上させ、環境への影響を低減するための改善に努力している。
華能集団は、今回のセミナーを機会に APEC 地域の政府・企業・研究機関が資源節約型の、
環境と調和のとれた社会の実現を目指して密接な協力を行い、クリーン・コール・テクノロジーを発展させていくことを心から希望する。

② 第 1 セッション Coal Demand Outlook 1 石炭需要予測 1
議長：経済産業省資源エネルギー庁資源・燃料部課長補佐 近藤 裕之氏（日本）

講演 1
Policy Tendency of Chinese Coal Industry Development
中国石炭産業開発の政策の方向性
Mr. Zhang Yong, Deputy Director, Policy Research,
China National Coal Association (CNCA)
中国煤炭工業協会政策研究部副部長 ジャン・ヨン氏（中国）中国石炭産業発展のための基本政策
 目的は、経済成長に伴って増加する石炭の需要を満たすこと。石炭の生産は 2002 年以
来毎年 1.5 億トン増加し、2006 年時点で生産量は 23.9 億トン。
 石炭産業は、他の産業に燃料と原料を提供する重要な基礎的産業、且つ、550 万人を雇用する大産業。困難と危険を伴う、労働集約型の産業である。
 中国には石油が少なく石炭が多いため石炭は今後もエネルギー構造の中心。生産されるエネルギーの 75％、消費されるエネルギーの 69％が石炭である。
 生産される石炭の約 50％は発電用で、中国の電力の 83％は石炭火力発電。生産される石炭の 80％以上が鉄鋼、建材、化学を含む 4 業種で消費される。
 社会主義市場経済体制に沿い市場原理に基づく開発・生産・経営を行うため、計画経済から市場経済、粗放型から集約型、の二つの転換を実施する。
 改革開放政策に沿い、国外の資源、国外の市場も活用。輸出は 2003 年に 9,400 万トンを記録したが、2007 年は 3,000 万トンの見込み。一部企業は豪州、インドネシア、モンゴルでの炭鉱開発を行っている。
当面の政策 2010 年の目標生産量は、第 11 次五ヵ年計画では 26 億トン、政府の調整目標では 28 億ト
ン、専門家の予測では 30 億トン。
 関連する政府の基本的文書として「石炭産業の健全な発展に関する若干の意見」（国務院国発 2005-18 号）がある。
 指導思想及び基本原則の中では、科学技術、資源利用効率、安全、利益、環境保護、大型石炭基地、地域経済との調和、石炭産業の堅実な発展、資源節約型社会、生産性の優劣による淘汰、企業の自主的発展、地方経済・社会の発展、等を重視している。
 改革の方向としては、資源有償使用制度の実施、環境配慮に係るモデル地域、重点企業の指定等。
政策の具体的項目
 大型石炭基地建設（13 の基地を建設し、国内生産量の 80％を賄う）。

 大型石炭企業集団育成（1 億トン級の集団を 6～8、5 千万トン級の集団を 8～10 形成する）。
 省エネ（資源を節約し排出を減らす方針。重点企業を指定)。
 環境対策（「循環型経済」を奨励。クリーンな生産を促進する法律を制定。クリーン・コー
ル・テクノロジーを開発）。
 安全対策（安全第一の方針。安全責任制をとり重大事故時の責任を追及。安全に問題のある炭鉱の閉鎖）。
 持続可能な開発
政策の具体的項目
 法制の整備（石炭法、鉱産資源法、を基本とする。炭鉱生産許可証と炭鉱安全生産許可証の発行制度）。
 11 次 5 ヵ年計画に基づく諸調整（小炭鉱の整理等）
 税制改革（所得税・増値税の改革、安全生産保証金等インセンティブの制定）。
 他、科学技術振興、教育訓練、労働保障等。

講演 2
Coal Demand Outlook in Malaysia
マレーシアにおける石炭需要予測
Mr. Hiew Char Loong, Senior Executive (Logistics),
TNB Fuel Services Sdn Bhd (Malaysia)
TNB 燃料公社 上級職（ロジ担当） ヒュー・チャー・ロン氏
2007 年７月時点のマレーシア半島部の発電設備容量は
19,023MW、天然ガス火力が 62.9％、石炭火力が 26.7％、水力が 10％で、石炭は天然
ガスとともに主要な発電用燃料となっている。マレーシアの電源構成は、1975 年には石油火力とディーゼルが合計 69%、水力が 31%であったが、政策的に石油依存度を減
らし多様化を図っており、2000 年には天然ガス火力 71.9%、水力 13.6%、石炭火力
11.4%、と天然ガスと水力を中心とし石炭の比率を増やす傾向にある。2010 年に石炭火力は 9,130MW になり、電力用石炭需要は年 2,100 万トンになると予想される。
マレーシアは国内の石炭埋蔵量が殆どなくほぼ全量を輸入に頼っているが、調達先をインドネシア・豪州・南アフリカ等に分散し、積出港も分散化すること、調達にあたっては 80％までを契約ベース 20％はスポットとし、契約は長期（5 年+5 年延長可）を中心として、更に個々の契約期間を交互にずらすこと等によりリスク対策を講じている。また炭質等を事前に審査し調達の迅速化を図っている。
インドネシアに関しては、亜瀝青炭の埋蔵量が豊富であるが、積出港が限られている
こと、炭質等についての基準が不明確であること、モンスーン季の気象が不安定で積出しに影響があること、石炭輸送に使う河川が乾期に水位が下がり川幅が狭くなって混雑すること、等の問題がある。
豪州と南アフリカに関しては、瀝青炭が豊富であるが、インドネシアに比較して輸送距離が長いので輸送費が高いこと、炭質等についての基準はあるがあまり明確でない
こと、豪州の輸送インフラが不充分であるため 35 日間・70 隻にも及ぶ滞船が生じること、更に港湾当局の調整の結果供給量が減ること、等の問題がある。
輸入炭については、混炭による瀝青炭・亜瀝青炭の質の低下を防止すること、購入する石炭の仕様がボイラーの設計範囲内に収まるようにすること、信頼できるサプライ
ヤーから供給を受けること、新しい銘柄の石炭は試験燃焼で事前に安定性を確認する
こと、新しい炭鉱は精査を行うこと、独立した第三者機関による評価を行うこと等により、品質の保持を図っている。
石炭と環境の問題についてマレーシアでは、一般市民に石炭は汚いものとの誤解があることに加え、環境 NGO の活動が活発で市民の支持を得つつある。環境関連の法的規制が厳しくなった結果、石炭火力については運転開始までさらに時間を要するようになり、建設費用・運転費用も増えた。
海外炭の調達は天候の影響を受けることが多く、カリマンタンでの豪雨による炭鉱と輸送路の水没、ニューキャッスルとハンターバレーの暴風雨による炭鉱の水没と鉄道
港湾への影響等の事例があり、契約上不可抗力とされると供給計画を見直さざるを得なくなる。
石炭価格は 2004 年の後半にかけて高騰した後一時沈静化していたが、最近再び高騰しており、また海上輸送費も再び高騰している。
この他、海外炭に関しては、マレーシア側内部で、ボイラーの設計と石炭の仕様が会わない場合が多いこと、IPP 同士の間で燃料を融通しあえるような柔軟性がないこと、電力供給が不安定で強制的な停電もあること、環境関連の法的規制が厳しくなった結
果、質とコストのバランスをとる必要があること、等の課題がある。

講演 3
Coal Demand Outlook in Thailand
タイにおける石炭需要予測
Mr. Samerjai Suksumek, Director, Strategic Energy Policy
and Planning Division, Energy Policy and Planning Office(EPPO), Ministry of Energy (MOE）(Thailand)
エネルギー省エネルギー政策計画庁エネルギー政策計画部長
サマルジャイ・スクスメク 氏（タイ）タイのエネルギー政策は、持続可能な成長のためのエネルギー資源の効率的利用と保全・開発を中心とし、天然ガス等国産エネルギーの強化、石油代替エネルギーの効率的な調達と利用の促進、製造業の競争力を増すためのエネルギー価格の安定、再生可能エネルギー・クリーンエネルギーの利用拡大、および市民の理解と協力を得ることを重点項目としている。
経済成長に伴いエネルギー消費は増えているが、基本的には石油・天然ガス中心で、石炭は 2001 年には 15％、2007 年には 17％となっている。
現在 PDP 2007（(EGAT 作成の 2007 年から 2021 年までの電源開発計画)を改訂中で、発電用燃料の優先順位、天然ガスへの過度の依存を避けるための石炭の重要性、等が記載されることとなっている。発電用エネルギー源の割合は、2016 年には天然ガスが 66～69%、石炭 16～20%、輸入電力 7～9%、再生可能エネルギー1～3%、石油はゼロとなっている。
2021 年には、水力発電やラオス・ミャンマー等からの輸入電力が増え、2020 年に原子力が運転開始となることから、天然ガス 63%、石炭 15％、水力及び輸入電力 10%、再生可能エネ
ルギー3％、原子力 9%となっている。
2006 年の需要は 3,000 万トンで、内 64％相当の 1,900 万トンが電力、1,100 万トンが製造業（セメント・製紙）であった。褐炭は、エネルギー供給源を多様化し、電気料金を低く抑える観点から、国内資源として重視されている。2006 年の石炭の供給量は 3,000 万トンで、内 1,900
万トンは国内炭の 84％を供給する EGAT の Mae Moh 炭鉱からの褐炭が中心、1,100 万ト
ンは主にインドネシア・豪州からの輸入炭で、カロリーが高く硫黄分が低い亜瀝青炭・無煙炭である。
2007～2021 年の国内炭の供給は年約 1,600～2,000 万トンで、内約 1,600～1,700 万トン
が Mae-Moh 炭鉱からだが、他の炭鉱の生産者の採掘権が期限を迎えることにより、国内炭は全体としては次第に減少していく。石炭の輸入は 2007 年から 2021 年にかけて、セメント用、製紙用を中心に増加する。
2021 年の需要は 5,537.6 万トン、これに対する供給は、国内から 1,572.2 万トン、輸入により
3,965.4 万トン、と予測される。2021 年の電力用炭の需要は 2,780.5 万トンで、IPP 及び SPP
向けは輸入炭、EGAT 発電所向けは Mae Moh 炭が中心だが、2011 年以降は新規火力用に石炭を輸入する計画。
1992 年、Mae-Moh 発電所で周辺住民や作物への被害が発生し、その後集塵機と脱硫装置の設置により問題は解決したが、石炭に対する悪いイメージが国内に定着し、別の石炭火力の計画が、反対運動により燃料の天然ガスへの変更と建設地の変更を余儀なくされるという事態に至った。これを教訓に、環境問題による石炭火力反対運動に対処するため、タイ政府は、
CCT の採用に力を入れている他、良質の海外炭輸入を奨励している。
この他、石炭火力発電所立地への市民の参加と理解を促進するため、発電所予定地周辺住
民の教育・文化、保健衛生等の生活環境整備のため、一定以上の規模の発電事業者に拠出を義務付けて、Community Development Fund（地域開発基金）を創設する計画。基金は、市民、政府、電気事業者、有識者等からなる委員会で管理される。

③ 第 2 セッション Clean Coal Power Generation クリーンな石炭火力発電所
議長：Mr. Jiang Minhua, Director of TPC/CSEE, President of TPRI（PR China）
中国電力エンジニア学会 事務局長・西安熱工研究院 院長 ジャン・ミンハ氏（中国）

講演 1
Status and Development of Chinese Coal-fired Power
Generation
中国における石炭火力発電所の開発と現状
Mr. Huang Qili, Academician, Chinese Academy of Engineering（PR China）
中国工程院 工程師 フアン・チリ氏（中国）2006 年、約 23 億トンの出炭の内、12 億トンが発電に使われた。
中国の発電設備容量は本年度 72 万 MW に達する予定である。2010 年には 84 万 MW に達するが、発電構成に占める石炭火力の比率は 78%から 70%になると予想される。中国の発電技術は先進的なレベルと比べると石炭消費量が 30～40
g/ kwh、水使用率が 30%～40%高い。これは年間 1.2 億トンの石炭、15 億 m3 の水を無駄遣いしていることになる。そのような現状を踏まえて、中国ではさまざまな技術開発が進められている。脱硫装置は全体の 14％に設置され、脱硝装置は初期段階である。第 11 次 5 カ年計画
において、石炭火力の発電効率の向上、設備の大型化、天然ガス、原子力発電の推進が挙げられている。
2006 年末までに 40 の超臨界圧ユニット（計 30GW）が導入され、その内 3 ユニットが 1GWの容量をもつ超々臨界圧ユニットである。効率も国際レベルに達している。統計によれば 150
基の 600MW から 1000MW 級の超々臨界圧ユニットが導入、建設、計画されている。
循環流動床ボイラについては中国工程院の独自特許の設計によって建設されている（210MW）。また、600MW の超臨界圧 CFB も計画中である。
脱硫装置の 90%以上は国産である。脱硫効率も 90～95%に達し、一部のメーカーは特許も獲得している。SOx 排出を 11 次 5 カ年計画中に第 10 次より 10%削減することを目標としている。中国は SOx 排出対策について後進国であり、5g/kWh だが、米国 8g/kWh、日本は0.2g/kWh である。中国は NOx 排出削減対策も初期段階である。
電力構成の適正化と発電所の大型化（小規模発電の閉鎖）に取組む必要がある。これは環境負荷軽減、発電効率の向上に繋がる。今後 4 年間で 50GW 分の小規模石炭火力発電所
及び 7～10GW 分の石油火力発電所を閉鎖する。
今後の潮流として超臨界、超々臨界圧ボイラが主体となるだろう。その次は循環流動層ボイラとなり、IGCC となる。GreenGen として IGCC、CCS 技術開発も進めている。

講演 2
The Role of Technology in Mitigating Global Climate Change
世界規模な気候変動緩和に係る技術の役割
Mr. Frank Princiotta, Director, Air Pollution Prevention andControl Division, Environmental Protection Agency (EPA) (US）
米国環境保護庁(EPA) 大気汚染防止・管理部長
フランク・プリンシオッタ氏（米国）
1992～2002 年の世界の CO2 排出の伸びは年 1.6％強（IEA データ）。その中で中国、インドの伸びが大きく、年 4％前後となっている。しかし、最新の 2002～2004 年のデータは世界平
均で年 3%を越えており非常にシビアなデータが出ている。
ここで IEA のベースラインをもとに作成した年 3%の伸びに置き換えると、地球温暖化に更に大きな影響がでる。
G8 リーダーと各エネルギー大臣の要請により、IEA は CO2 削減の諸方策について“Accelerated Technology (ACT) Senarios”を策定した。このシナリオは、研究開発の強力な推進と成功を前提としており、その結果、2030 年以降大規模な CO2 削減が実現するとしている。CO2 削減を 1 トン当り 25 ドル以下で可能とする技術を目指し、優遇制度、減税措置、補助金、取引制度といったインセンティブも政策として考えられている。IEA によると最も CO2 排出が多い分野は発電分野で、次は運輸分野である。2050 年を見通した場合、発電分野の排出量、伸びが最も多く、ACT による CO2 削減量も多い。
2030 年から ACT の開始によって 2100 年には気温上昇を 2 度に抑えるシナリオである。
そのために中国とインドの CO2 増加率の低減、米国の CO2 削減が必要で CCS 技術の開発が重要となる。この CCS の開発には CO2 の回収について主に下記 3 つの技術の開発が必要。
①微粉炭焚きボイラからの CO2 回収について②IGCC からの CO2 回収について③酸素燃焼によるからの CO2 回収について
原子力発電所は重要な選択になる。
2100 年には必然的に 2 度の上昇は起きる。気温上昇を 2.5 度以下に抑えることは非常に困難な挑戦となるであろう。地下貯留、微粉炭焚きボイラ CO2 回収、IGCC、酸素燃焼、先進的原子力発電の開発が重要である。

講演 3
GreenGen Technology

GreenGen プロジェクト

Mr. Hu Shihai, Assistant President, China Huaneng Group (PRChina)
中国華能集団公司 部長補佐 フー・シハイ氏（中国）中国の発電設備容量は 2006 年に 620GW を越え、火力発電所が75%を占め、その 95%は石炭火力であった。
世界的に見ても IEA によれば、発電から生じる CO2 が最も多い。
GreenGen のフローを説明すると、まず石炭をガス化し、その時発生するスラグは建設資材として活用する。ガス精製の過程で硫黄を回収し利用する。精製ガスは CO2 と水素に分離され、CO2 は僅かであるが工業利用や石油の二次回収（EOR）に使われたり、深海に投棄される。
水素は発電や化学原料に加工される。
GreenGen 株式会社は NDRC、MOST の支援のもと、他の国内 7 エネルギー企業と連合して設立された。中国華能集団は 51%、他の企業は各 7%の株を所有している。
GreenGen の目的は石炭ガス化による水素製造、水素発電及び CCS。そして、石炭発電の高効率化とすべての有害物質、CO2 のゼロエミッションを目指し、中国独自の革新的技術を習得することにある。最終的には商業ベースの実証を行う。
第 1 ステージ（2006～2009 年）は 2,000t/d の石炭ガス化実証試験、250MW の IGCC プラ
ントの建設、実験室建設などを行い、第 2 ステージ（2010～2012 年）は 3,500t/d×1 または2,000t/d×2 のガス化の比較、水素製造、CCS、燃料電池の試験などを行う。最終ステージの第 3 ステージ（2013～2015 年）では燃料電池発電、水素タービン複合発電、CCS を含む
400MW の商業ベースのデモンストレーションプラントを建設し、ニアゼロエミッションを目指す。
中国華能集団は 2007 年 4 月に 400MW×2 の IGCC プラントを天津工業団地に建設することで天津市と合意した。現在は空気分離装置、ガス化炉の建設が終わり、ガスタービンは GE、シーメンス、MHI の間で入札中である。
CCS について、中国華能集団北京発電所において 3,,000～5000t/d の燃焼後 CO2 回収設備が建設され、2008 年 7 月までに稼動予定である。これは豪州 CSIRO との共同研究で実施される。
また、同時期に中国華能集団と TPRI は中国と EU との CCS プロジェクト（COACH）に参画
し、英国との CCS プロジェクト（NEZC）にも参画予定である。

④ 第 3 セッション Clean Coal Power Generation クリーンな石炭火力発電所
議長：Mr. Huang Qili, Academician, Chinese Academy of Engineering（PR China）
中国工程院 工程師 フアン・チリ氏（中国）

講演 1
How

can

environmental

regulations

promote

clean

coal

technologies in developing APEC economies?
APEC 内発展途上国においての CCT を促進するための環境規制の導入理由
Ms. Jette Findsen, Deputy Program Manager, Climate Change,
Science Applications International Corporation（US）
サイエンス・アプリケーションズ・インターナショナル・コーポレーション（SAIC/米システム開発大手）気候変動部 プログラム担当副部長 ジェット・フェンデソン氏（米国）
CCT 導入による APEC 域国の新石炭火力発電の拡大への環境保全について現況を調査した。
APEC 域国の排出基準は中国、インド、インドネシア、フィリピン、タイ、ベトナムと様々で、今後、CCT が導入されることにより排出基準への影響が予測される。
先進国の排出基準は、NOx、SOx、PM の排出に関して、排出を最低限にする最適な排出基準、及びその技術（米国）や単位出力当たりの排出量制限（カナダ）、州による
NOx や PM 排出制限
（豪州）、
国の排出制限やプラントサイズや設置位置により変わる。
排出制限（日本）等、これも様々であるが、途上国と比較し、高い排出基準レベルにある。
また、米国やカナダでは石炭火力からの水銀の排出が新設火力の適用や州による既設火力への排出制限が適用されることになった。
その他、石炭燃焼副生成物に関して、先進国では一般的には有害な廃棄物としてではなく、発生量やその発生物の質により、土地埋め立てや鉱山への充填、リサイクル品への適用には報告義務等が課せられている。
途上国においては量と廃棄方法の報告、一部土地埋め立てへの制限があるのみである。
温暖化ガス排出においても先進国では排出権トレードや課税、CO2 固定義務を規則する動きも近年加速化しつつある。
一方で、排出抑制に対する開発技術の適用は、中国においては、大型の SC、USC ボ
イラの適用や IGCC の開発が進んでいるが、他途上国では脱硝設備の設置義務はない
等、新しいボイラへの脱硫設備の設置の検討や、流動床ボイラの設置が検討されている状況で、プラントの効率等には及んでいない。

環境規制はコスト上昇を伴なうため現状では進展しにくい。
NOx、SOx、PM に関しては先進国保有の既存技術で対応できるが CO2 排出が課題として残るため、高効率化に関する規則や技術標準、機器効率目標の設定が必要である。
また、APEC 域での共通した環境規制の標準の設定も必要と思われ、それに向けた技
術や技術標準の整備が必要である。中長期的には CO2 も現環境規制対象と同様に扱う
ことや炭素価格の制定やトレードに向けた具体的方策が重要である。
Q&A
Q： 中国の現環境規制をどう考えるか。CO2 や水銀の場合はどうか。
A： エネルギー消費の拡大と発電技術の進歩により環境規制が施行されてきている。これまでにも SOx の規制や NOx の規制が施行されてきた。CO2 の場合、まずは SC やUSC の導入によりプラント効率向上を考えることが、エミッションを減らすことに繋がる。また、水銀の場合、カナダ－米国間の影響が及ぼすものとして規制をかけるよ
うになったが、これも中国の場合、まずは効率向上により石炭の使用量を減らすことが先決と考える。

講演 2
Introduction of the First Domestically Manufactured 300-MW
CFB Boiler in China
中国初国産 300MW 流動床ボイラーについて
Mr. Jin Yaohua, Deputy Chief Engineer, China Datang
Corporation（PR China）
中国大唐集団公司 副主任エンジニア ジン・ヤオハ 氏（中国）中国では、1987 年に 10t/h の流動床ボイラが立ち上がって以来 2,000 機以上が稼働した。今回中国製ボイラが、国家計画により西部から東部への送電計画に則り、9 セットの 300MW を含む流動床ボイラが稼働し出した。
国産初 300MW の流動床ボイラは Honghe プロジェクトにより No.1、No.2 が 168 時間の試運転を経て 2006 年 8 月 27 日に全負荷運転を開始、順調に経過している。
本ボイラの設計はハルビンボイラ公司により亜臨界圧条件の自然循環式単缶型で設計が行われ、大唐国際紅河発電有限公司の建設により、これまで輸入していた循環流動
床ボイラ以上の性能を持つボイラの製作となった。このボイラの開発前、135MW の開発を行ったが満足な結果が得られず、この結果をもとに F/S と検討を重ねた。そして大唐国際紅河発電有限公司が新しい技術開発のリスクとライセンス料を払う形で実行にかかった。これによりトライアルランを含めたプロジェクトの実行に係る全てのプ
ロセスの品質管理は行えるようになった。
スケールアップに係る大型ボイラ開発において革新的技術として大型通風機、機器内

部の酸洗浄、設備乾燥技術等が上げられる。操業開始後 No.1 が 11,054 時間、No.2 が9,665 時間運転を行っており、稼働率はいずれも 95%以上である。
環境対策の実績として硫黄分 1.7%を持つ石炭の利用が脱硫率は 95%を超え、SOx 排出基準である 1,200mg/Nm3 に対して 330 mg/Nm3 の好実績であり、また低温燃焼によるNOx は 139mg/Nm3 であった。また、2 塔の ESP による集塵効率は 99.62%で排出濃度は 67.4 mg/Nm3 であった。
運転管理及びメンテナンスについて、適性流動層維持のための開始エア吹き込み圧や空搭速度、微粉炭粒径、スラグ排出、スタートアップ時の油の使用節減等について検討を加え改善を行った結果、350 万元の節減が可能となった。その他バーナー部チャンネルと水冷チャンバー間の伸縮ジョイント部の非鉄金属材料やその技術の国産化も大きく改善された。

講演 3
Clean Coal Utilization in Coal-Fired Power Plant
CCT を用いた石炭火力発電所
Dr. Sungchul Kim, Group Leader, Combustion & Thermal
Performance Group, Korea Electric Power Corporation（Korea）
韓国電力公社(KEPCO) 燃焼発電技術グループ グループ長
スンチュル・キム博士（韓国）韓国は国民一人当たりのエネルギー消費量は先進国諸国と大差はないが GDP 当たりのエネルギー消費量が大きいことが特徴である。
1970 年代よりエネルギー資源の安定供給を目標に、各エネルギーのベストミックスを目指し、原子力や新エネルギーにも取組み、油に偏ったエネルギー構成を是正してきた。
現状を見ると、一次エネルギーで 3%、電力量で 3.2%の年間の伸びを見せている。発電量では、2015 年必要電力量見込みは 456,443MkWh で、2005 年実績 332,413MkWhの 1.4 倍となる。
第 3 次電力需要計画での 2015 年燃料別発電量構成は原子力が 27.9%、石炭 28.4%、
LNG28.1%、油 2.6%、水力その他が 13.0%と計画しており、各燃料別発電設容量も適当なバランスを維持しており、今後原子力と石炭をベースロードとし油・LNG を負荷対応としている。
石炭の利用量は瀝青炭が年々大きく伸びており、国産の無煙炭は減少するものの豪州、インドネシアを中心に輸入炭に頼っている。
東海（Tonghae）石炭火力発電所は韓国最大の 200Mwe×2 台の流動層ボイラである。
熱量 4,600kcal/kg、灰分 39%の国産の低品位無煙炭を使用し 1 号機が 1998 年より、2

号機が 1999 年より順調に稼働している。
韓国においても高効率 IGCC は導入の検討を加えているところであるが、現況では最新鋭の微粉炭火力と効率や環境値は大差なく、建設コストや必要設置面積に難がある。
米国や欧州のデモンストレーション IGCC を参考に韓国産の IGCC の運転を 2012 年を目標に世界一の 300MWe 効率、42%超の経済性を持つ IGCC 建設を目指している。
開発は設計 3 年、建設 3 年、運転実証 2 年の 3 フェーズにて計画しており、ガス化炉の設計を重工業メーカーと研究所、トータル機器設計、及び建設・運転を電力会社、
ユニットプロセス開発を大学と研究所が分掌することにより開発を進めている。
韓国は京都議定書における附属書Ⅰ国ではないが、次期議定書の削減義務国になると想像され、GHG 削減技術開発と酸素燃焼や CO2 の分離回収固定技術が必要となる。
Q&A
Q：

既設の火力発電所の CO2 対策の方向性は何か。

A： 排ガス全量から CO2 を処理するよりも酸素燃焼技術を導入して CO2 濃度を高めて処理することが良いと考えている。いずれにしても現状の火力発電所に設備を導入することになるので、所内動力の増加によるプラント効率低下は免れないが、排ガスの化
学処理より、酸素燃焼の方がエネルギーロスは小さくて済むと考えている。

⑤ 第 4 セッション Coal Demand Outlook 2 石炭需要予測 2
議長：Ms. Louise Tamascheke, Assistant Manager, Coal Policy Section, Resources
Division, Department of Industry, Tourism and Resources (DITR) （Australia）
産業観光資源省 資源部 石炭政策課 課長補佐 ルイス・タマシュケ氏（豪州）

講演 1
Coal Demand Outlook in the Philippines
フィリピンにおける石炭需要展望
Mr. Restituto G. Taganas, Jr., OIC-Assistant Director, Energy
Resource Development Bureau, Deparment of Energy(DOE),(Philippines)
エネルギー省 エネルギー資源開発局担当副部長
レストウト・タガナス氏（フィリピン）フィリピンの 2005 年から 2014 年にかけてのエネルギー計画は、エネルギーの自立、
経済成長と雇用創出、良い統治と汚職の防止、社会正義とベーシックニーズ、教育と若者の機会、という 5 つの改革のパッケージを基礎としている。

エネルギー分野の課題は、


エネルギー自給（国産エネルギー資源の探査と開発・利用の促進、バイオマス・太
陽光・風力・海洋エネルギー等再生可能エネルギー開発の強化、石油代替燃料の利用拡大、エネルギー効率向上・省エネ、海外との連携）



効率的で競争力あるエネルギーセクターの確立（公共輸送機関の民営化、投資家に魅力のある環境作り）
石炭政策は国産資源の探査と開発の活性化の一環として位置付けられている。採炭について国際入札方式（Philippine Energy Contracting Round）を継続。炭層メタン、安全、等のプロジェクトを推進。2006 年末時点の可採炭量は約 3 億 3,000 万トン。
一次エネルギーの変化を見てみると、2000 年には、石油が 37.53％、バイオマスが24.8％、地熱が 22.89％、石炭が 10.06％、水力が 4.45％、天然ガスが 0.26％だったが、2006 年には石油が 35.25％、地熱が 22.84％、バイオマスが 15.7％、石炭が 13.49％、天然ガスが 6.42％、水力が 6.28％、だった。今後、2010 年には地熱が 36.05％、バイオマスが 25.25％、石油が 11.4%、天然ガスが 9.37％、石炭が 8.55％、水力が 8.04%、
エタノール等が 1.01％、太陽光・風力等が 0.32%、2014 年には地熱が 34.09％、バイオマスが 24.54％、天然ガスが 14.05％、石炭が 10.89％、水力が 7.44%、石油 が 6.81%、
エタノール等が 1.08％、太陽光・風力等が 0.3%と予測される。
発電設備の現状は、石炭火力が 26.35%、水力が 20.54%、天然ガス火力が 17.43%、地熱が 12.79％、ディーゼルが 12.6％、ガスタービンが 6.02%、その他火力が 4.10%、
風力が 0.16%となっている。
電源構成の変化を見ると、2000 年には、石炭火力が 36.79%、
地熱が 25.67％、石油火力が 20.28%、水力が 17.22%だったが、2006 年には、天然ガスが 28.82%、石炭火力が 26.93%、地熱が 18.43％、水力が 17.5%、太陽光・風力が0.1%だった。今後、2010 年には、石炭火力が 34.87%、天然ガスが 19.59%、地熱が14.93％、水力が 9.63%、石油火力 3.36%、風力が 0.24%、その他 17.38%、 2014 年には、石炭火力が 39.68%、天然ガスが 24.63%、地熱が 17.26％、水力が 11.72%、石油火力 3.36%、風力が 0.29%、その他 3.05%と予測される。
フィリピンにおける 1977 年から 2006 年までの石炭の需要動向を見ると、1995 年以降
電力用の消費が急激に伸び、約５倍以上にまで増加してきた。生産についてはほとん
ど伸びていないので、需給ギャップを埋めるため輸入が増えた。2006 年の石炭消費は
合計約 1000 万トンで、内、73%が発電、23%がセメント製造に用いられた。
今後の石炭需給見通しは、2010 年の需要は 1,087 万トン（内、発電用が 919 万トン、セメント用が 141 万トン、他鉄鋼等）、供給は国内炭 379 万トン及び輸入 708 万トン、2014 年の需要は 1,213 万トン（うち発電用が 1037 万トン、セメント用が 148 万トン、他鉄鋼等）
、供給は国内炭 524 万トン及び輸入 689 万トン、と予測される。

講演 2
Coal Demand Outlook in India
インドにおける石炭需要展望
Mr. K.S. Kropha, Joint Secretary, Ministry of Coal (MOC)(India)
石炭省 次官補 KS クロファ氏（インド）
インドのエネルギー政策ではセキュリティーが重視され「全ての市民にライフラインであるエネルギーを、支払い能力の有無に係らず供給するとともに、安全且つ便利で妥当な価格でいつでも入手でき、予想されるショック時にも信頼に耐え得るレベルのエネルギーを求める市民の需要に応じること」が政府の責任とされている。インドの人口一人当りのエネルギー消費量は 2003 年に石油換算で 439kg だったが、世界平均 1,688kg、中国 1,090kg、アメリカ 7,835kg と比較して非常に低い。
エネルギー・セキュリティーのためのリスク削減策として、エネルギーの生産と使用における効率の向上、輸入依存度の低減、供給源の多様化、国産エネルギー源の拡大、リスク予防策として、供給ショックへの耐性をつけること、エネルギーを輸入しまた市場リスクに対応できる能力をつけること、技術的なリスクに対応できる余力をつけること、が挙げられている。
インドにとって石炭は主要なエネルギー源であり、2003～4 年の一次エネルギー源のシェアは全体の約 50％で、2031～32 年時点でもこの率は変わらないと予想される。現在のインドの全商業エネルギー需要の 59％は石炭によって賄われている。石炭生産量の 78%は電力部門で消費されており、発電の 75％は石炭火力によるものである。
石炭の生産は中央政府の統制下で、国営の Coal India 社を中心に行われている。また、石炭を使用する鉄鋼、電力、セメント、等の企業に割り当てられた自社用 Captive 鉱区(現在165)でも生産が認められている。
石炭の価格は以前は管理価格であったが、2000 年以降自由化された。
外国資本の直接投資については、Captive 鉱区に限り 100%認められている。
石炭の輸入については自由化されており輸入量の制限もない。輸入税は灰分 12%未満の原料炭は無税、灰分 12%以上の原料炭および灰分に関わりなく一般炭は課税（5%）となっている。輸入に係る問題点としては、海上輸送費が高いこと、港湾と内陸輸送インフラが未整備であることが挙げられる。
今後の政策上の課題としては、生産拡大のため民間企業と外資の参入の場を増やすこと、生産の基盤(道路・鉄道、人材、採掘機器の国産能力)を整備すること、用地を確保すること（住民移転と跡地復旧を含む）、大規模採掘および坑内掘りに対応した技術を導入すること、選
炭・炭層メタンの採取・ガス化・液化等のクリーン・コール・テクノロジーを導入すること、適正価格設定等のための独立機関を設置すること、Captive 鉱区の割当てを入札により行うこと、石炭輸入のための港湾と内陸輸送インフラを整備すること、国営企業により大きな自主性を与えること、が挙げられる。
インドの石炭埋蔵量は世界第 4 位、石炭生産では世界第 3 位である。インドの石炭の国内需
要は、第 11 次 5 ヵ年計画では、2011 年度に 7 億 3,110 万トン、2016 年度には 11 億 2,500
万トンまで増加すると予測されるが、需要の中心は電力である。2024 年度に予測される需要は 12 億 67 百万トン、供給は 10 億 86 百万トンで、1 億 81 百万トンのギャップが生じる。このギャップには輸入で対応することになるが、2005 年度における輸入は 27 百万トンであった。

講演 3
Coal Demand Outlook in Korea
韓国における石炭需要展望
Dr. Jaeho Kim, Head, Technical Research Institute,
Korea Coal Corporation (KOCOAL) (Korea)
韓国石炭公社(KOCOAL) 技術調査研究所 所長
ジャエホ・キム博士（韓国）
韓国の石炭（無煙炭）は、揮発分が低く、灰分が多く、カロリーが低く、発火点が高く、反応性が低い。主に家庭の暖房・調理用燃料としての練炭の製造に用いられている。尚、練炭の製造にあたっては、亜瀝青炭は灰分が少なく練炭の形状維持が難しいので混合する時は、亜瀝青炭の比率を 15％以下にする必要がある。他に、韓国の国内炭は政府の石炭産業支援
策を得て発電にも用いられている。
生産は毎年 24 百万トンずつ増加してきたが、韓国の経済成長に伴い、生産性が低く価格が高い石炭に代わりガス等が好まれるようになり、政府は政策を変更し生産削減が行われた。その結果、1988 年以降国内炭の生産は激減し、炭鉱も 1988 年には 347 あったものが 2005
年には７箇所まで減った。この結果、炭鉱地帯は経済活動が不活発となり、所得水準が落ち
人口も減り社会問題が発生した。1988 年に 2400 万トンだった生産量は、2006 年には 280
万トンとなり、労働者数も 62,259 人が 5,876 人にまで減少した。
しかし、最近の石油高騰により国内炭の需要が徐々に伸びており、需給ギャップが生じている。
2001 年には需要 450 万トンに対し供給 330 万トンで、政府が備蓄分 700 万トンを放出し当座のバランスを保った。
国内炭の今後の需要は、練炭については年 5.4%で増加し 2006 年の 241 万トンから 2010
年には 293 万トンになると予想される。また発電用については、2006 年の 235 万トン規模で今後も推移し、2010 年にも同量の 235 万トンになると予想される。
現状の国内炭生産抑制策のもとで、このまま年産 280 万トンの生産規模が維持されれば、韓国産無煙炭の需給ギャップは拡大し、2009 年には政府の備蓄も底をつくと予想される。政府

は需給バランスを保つため政策的に生産と消費を調整していく方向で、韓国石炭公社（KOCOAL）としても増産に備える予定。
一方で、政府は、旧炭鉱地帯振興のため、補助金の交付や地域に新しい産業を興すための企業への優遇措置等を実施。
また、政府は瀝青炭を確保するため、政策的に海外炭鉱開発を促進している。
海外炭については、韓国では発電用等のための瀝青炭の消費が毎年増加している。このため韓国は世界第二の石炭輸入国となっている。韓国は、輸入炭価格の高騰を通じ、需給のコントロールが難しいことを経験している。このため韓国としては、海外炭鉱開発に力を入れているが、権益を有する海外の瀝青炭炭鉱は少数で、他国との競争も激化しているので、瀝青炭の入手は東アジアで困難になりつつあると考えている。
2005 年の瀝青炭輸入は合計約 6,900 万トンで、国別では、豪州が 43％で約 3,000 万トン、中国が 26％で約 1,800 万トン、インドネシアが 19％で約 1,300 万トン、カナダが 6％で約 400
万トン、ロシアが 5％で約 300 万トン、であった。また、用途別では、電力向けが 66％で約4,600 万トン、鉄鋼向けが 25％で約 1,700 万トン、セメント向け他が 10％で約 700 万トンであった。
今後の瀝青炭の輸入は、2007 年に約 7,500 万トン、2008 年に約 7,900 万トン、2009 年に
約 8,600 万トン、2010 年に約 9,300 万トンと予想される。
韓国による海外炭鉱の開発は、豪州、中国、インドネシア、カナダが中心で、2004 年時点で、豪州が探査中 2 箇所・生産中 8 箇所、米国が生産中 1 箇所、カナダが生産中１箇所、インド
ネシアが探査中 1 箇所、生産中１箇所、中国が探査中 2 箇所、ロシアが生産中 1 箇所となっ
ている。

講演 4
Coal Demand Outlook in Chinese Taipei
台湾における石炭需要展望
Mr. Jin-Sheng Su, Bureau of Energy (BOE),
Ministry of Economic Affairs (MOEA)(Chinese Taipei)
経済部能源局 ジンシェン・スー氏（台湾）台湾は、狭い土地に多くの人口が居住しているが、エネルギー資源は限られており、エネルギー供給のほぼ全量を輸入に依存している。エネルギー需要は以前から伸び続けており、今後も引続き増加することが見込まれている。エネルギー供給における過去からのシェアの変化を見ると、石油と原子力及び水力の比率は減っており、天然ガスと石炭の比率が上がっている。
石炭については、台湾にも炭鉱があり 1964 年から 1968 年まで毎年 5 百万トン以上の石炭を生産していたが、コスト面の理由により、2001 年以降は全量を輸入している。輸入量は 2000

年には 45.4 百万トンだったが 2006 年には 62.2 百万トンまで増えた（うちインドネシアからは13.4 百万トンが 24.1 百万トンに、豪州からは 17.6 百万トンが 22.3 百万トンに増加。その他
輸入元はカナダ、中国等）。
石炭需要の中心は電力で約 77％を占めている。電力向け石炭の需要はこの 20 年間年 18％の率で伸び続けてきており、今後も拡大していく見込みである。電力以外の需要先は鉄鋼・セ
メントであるが、伸びは電力ほどではない。
台湾の石炭政策は、内外の石炭事情、市場の自由化、環境への配慮を念頭に、安定供給の確保、エネルギー効率の改善、環境保全、研究開発の強化、を柱として、備蓄の義務付け、調達先の多様化、財政上の優遇措置、省エネの強化、コジェネレーションの奨励、超臨界ユニットの導入、総合的クリーンエネルギー政策への適合、SOx、NOx、CO2 の排出の規制強化、IGCC を中心とするクリーン・コール・テクノロジーの開発等を重点項目としている。
石炭については、今後、2010 年には需要が約 65 百万トン、供給が約 68 百万トン、2015 年には需要が約 72 百万トン、供給が約 75 百万トン、2020 年には需要が約 89 百万トン供給が約 92 百万万トン、2025 年には需要が約 103 百万トン、供給が約 109 百万トン、になると予測される。
石炭の使用に伴って環境対策の重要性が増しているので、台湾は、APEC 等の場を通じて、国際的な協力によって共にクリーン・コール・テクノロジーの開発を推進することを希望している。

講演 5
Coal Policy of Japan 日本の石炭政策
Mr. Hiroyuki Kondo, Deputy Director, Coal Division,
Agency for Natural Resources and Energy (ANRE),
Ministry of Economy, Trade and Industry (METI), Japan
経済産業省 資源エネルギー庁 資源・燃料部 石炭課 課長補佐
近藤 裕之氏（日本）
2 度の石油ショックを経てエネルギー多様化を進めてきた日本にとって、石炭は一次エネルギ
ー供給の約 20％を占め、石油（約 40%）に次ぐ重要なエネルギー源となっている。現在日本は
主に豪州、インドネシア、中国から石炭を輸入しており、世界最大の一般炭輸入国となっている。日本の石炭需要は電力用を中心に一貫して伸びてきている。
アジア地域の石炭消費は、2003 年には約 24 億トンだったが、今後、中国とインドを中心に2010 年には約 37 億トン、2020 年には約 46 億トンまで増加すると予想される。
日本は、今後の世界的な石炭の利用拡大に対応し、自国への安定供給確保と国際的な需給の安定化を図るため、以下のような石炭関連技術に係る施策を引続き推進する。


産炭国への、坑内掘技術、低品位炭の改質、地質構造調査等に関する国際協力

CO2 等の環境負荷低減のための、利用効率向上に資する IGCC、IGFC 等の技術
や CO2 回収・固定化技術の開発（日本の石炭火力発電所の熱効率は世界最高水
準）

新たな多様な用途への石炭利用拡大のための、石炭部分水素化熱分解技術(ECOPRO)、石炭利用 CO2 回収型水素製造技術、石炭直接液化技術の開発



資源制約を低減するための、低品位炭改質技術（ＵＢＣ）の開発



石炭灰を低減するための、無灰化技術(Hyper-COAL)の開発



クリーン・コール・テクノロジー移転のため産炭国の技術者を招いて日本で行う研修



産炭国に日本の専門家を派遣し現地でＣＣＴセミナーを通じて行う研修



ＣＣＴモデル事業の実施

地球温暖化対策として日本は、以下の骨子による戦略「美しい星 50」を世界に提案した。
１．「温室効果ガスの世界全体の年間排出量を現状に比して 2050 年までに半減する」という長期目標と、実現に向けての「革新的技術開発」による「低炭素社会づくり」
２．2013 年以降の温暖化対策の国際的枠組構築に向けた三原則① 主要排出国が全て参加し京都議定書を超え世界全体での排出削減に繋がること② 各国の事情に配慮した柔軟且つ多様性のある枠組みとすること③ 省エネなどの技術を活かし、環境保全と経済発展とを両立すること
３.日本として、京都議定書の目標達成を確実にするため国民運動を展開すること
中でも石炭ガス化により、ガスタービンと排熱による蒸気タービンとで発電し、回収した水素も利用して高効率の発電を行うとともに、CO2 の回収・貯留(CCS)を行う「革新的ゼロ・エミッション
石炭火力発電」技術の開発には最も力を入れており、米国とも協力している。

⑥

第 5 セッション クリーンな石炭火力発電所 Clean Coal Power Generation

議長：Mr. Ni Weidu, Academician, Chinese Academy of Engineering (PR China)
中国工務院 工程師 ニー・ウェイドゥ氏（中国）
講演 1
Environmental Protection Technology Status and Development
Orientation in Coal-fired Power Plants
環境保全技術の現状と石炭火力発電所の開発
Mr. Wang Zhongqu, Director, Safety and Operation Department,
China Guodian Corporation (PR China)
中国国電集団公司 保安管理部 部長 ワン・ゾング氏（中国）中国における発電設備容量は年々増強され 2005 年末 5 億kWを超えた。総発電電力量のうち80%以上が石炭火力発電によるものである。発電設備容量の火力発電は全体の 75%を占め、発電のうち 95%が石炭火力で、中国国電集団公司での大気汚染防止された後の 2006 年の煤
塵発生量は 310 千トン/年、SO2 が 1,270 千トン、NOxが 690 千トンであった。
中国における環境保全に係る大気汚染防止技術の開発、普及は喫緊の課題であり、各種の実用化研究が進められている。例えば南京電力保安院のバグフィルターと膜技術による排水処理技術は国産の排水処理技術をリードしている。
火力発電所の環境保全技術として煤塵処理には、旋回式パルススプレー式集塵方法や固定
パルススプレー式集塵、及びバグフィルターによる集塵方法がある。
また、大気汚染防止に係る硫黄酸化物排出抑制技術として排煙脱硫技術があり、その方法には乾式及び湿式がある。今後は窒素酸化物排出抑制が同時に行える排煙脱硫技術が期待される他、FGD機器の高効率、省エネ型、小型化の研究が進められている他、FGD副生成物の利用範囲の拡大も望まれている。その他、窒素酸化物排出抑制のための低NOxバーナーや脱硝装置の導入も研究が進められている。
排水処理技術では、従来の排水処理方法に加え、循環処理水法や海水の淡水化利用技術
や石灰法による処理方法、微/超細フィルターによる処理方法の実用化研究が進んでいる。内陸部にある火力発電所は特に省水型が求められるため、排水のリサイクル利用や省水型の各機器の導入が必須である。
Q&A
Q: 脱硝設備の導入は技術開発よりもコストの面で導入インセンティブが働かず導入が遅れていると考える。導入への考えはあるのか。
A: 脱硝のみならず、脱硫も含みコストがかかる。しかしながら、政策によりコスト面、技術面をクリアするように進捗している。国際的コラボレーションも必要となる。

講演 2Energy Saving of Coal-fired Power Plant
石炭火力発電所における省エネルギー
Mr. Jin Donglai, Deputy Director,
Safe and Operation Department, China Power Investment
Corporation (PR China)
中国電力投資社 保安管理部副部長 ジン・ドングレ氏（中国）2006 年現在の中国における総発電量は 2834.4tWh である。そのう
ち火力が大部分（83%）を占め 2,357.3tWh、水力が 416.7tWh、14.7%である。
近年の火力発電は開発が進み、世界第二位の総発電設備容量 622GW の内 484GW で77.82%を占めるようになり、次期 5～10 年は同様な増加の傾向を示すものと思われる。主要な

火力発電の燃料となる石炭の埋蔵量は 8,230 億トンで、残存の経済的可採埋蔵量は世界の10%にあたる 1,392 億トンである。
中国は世界第二位のエネルギー生産・消費国でもある。エネルギー自給率は 90%になる。
2006 年、石炭の生産量は 23.7 億トン、原油の生産量は 1.84 億トン、天然ガスの 585.5 億 m3である。石炭は石炭火力発電所にて 11 億 4,200 万トンが消費された。
豊富な埋蔵量を持つ石炭が中国で利用され始めて僅か 100 年であるが、石炭資源探査と安定的な利用について深刻な問題を抱えている。
第 11 次 5 ヵ年計画ではエネルギー資源の保護は中国の基本的政策となった。
省エネルギーに係るガイドラインとして、科学的なコンセプトに導かれることによる一次エネル
ギー消費の縮減、経済成長に係る構造の変革、技術開発の加速、安定的な経済と社会構築のためのエネルギーの高効率化を目指し、本 5 ヵ年期間中に 20%の GDP 当りの省エネルギーを達成することとしている。
石炭火力発電について、現状では中国の発電における石炭消費量は 366g/kWh で先進国より 30g/kWh 高く 6,700 万トン/年（原炭にして約 1 億トン）が多く燃焼されていることとなり、石炭利用効率を上げることは重要で喫緊の課題である。日本の場合 299g/Kwh、韓国の場合
300g/Kwh と大きく隔たりがある。現在大型で高効率のボイラの導入が進んでいるが、2005 年
62 基の 600Mw 級ボイラ、349 基の 300MW 級のボイラが稼働しているが、中国におけるボイラの平均出力は 98MW と小型で低効率のボイラが数多く稼働している。現在導入している
600Mw 級超臨界圧ボイラ、超々臨界圧ボイラでさえ 5～10g/kWh、10～15 g/kWh 石炭消費量が高い。これらの原因としてボイラ設計仕様まで到達せず運転がなされおり最適化を図ることが必要である。また、主要な構成機器である粉砕機や送風機等の最適化が図られていなかったり、最新の技術が導入されていなかったりすることに起因すると思われる。その他、経済的な運転管理技術が未熟であったり、機器の信頼性が低いことによる稼働率の低下や、燃料価格の変動により、度々の使用炭質の変更が行なわれ最適化不足等が上げられる。
また新ボイラの導入があまりにも過急なため、設計や建設時の最適化不足も見られる。これら
はボイラの導入や運転に当り省エネルギーの考え方が不足している。
省エネルギーを柱とした発電事業構造調整と高効率の新技術の導入が課題となる。今後
600Mw 以上のボイラには 93～94%のボイラ効率を持つ超々臨界ボイラで、過熱機のチューブ材の選定や 3D デザインによる蒸気タービンの最適化を測り、ポンプやファンへのインバータ
ー制御電動機の導入、高電圧機器の導入、燃焼伝熱面のスートブローによる伝熱効率維持、予熱器での蒸気リーク量の低減、プラズマ点火採用や高温空気吹込み点火による起動時の重油使用の低減、最適運転を行うための各機器や状況を監視管理する SIS の導入、最適な負荷調整機能の導入、省エネ型脱硫装置の選定等を盛り込み、石炭消費量 280～
310g/kWh のユニットを目指すことと、低効率小型（100MW 以下）のボイラを総計 50,000MW
本計画期間中に廃止することした。

講演 3
Promotion of Energy Conservation and Consumption Reductionin Coal-fired Power Plant with Preserved Efforts in Adopting
Advanced and Higher Parameter Units
先進的高パラーメーターを持った石炭火力発電所の省エネルギー開発
Mr. Liu Guoyue, Deputy Manager General, Huaneng PowerInternational Inc., (PR China)
貨能国際電力有限公司 副部長 ルー・グオエ氏（中国）
貨能国際電力公司は 1984 年貨能電力公司として設立以来、4 プロジェクトを推進し三菱や GE の 350MW の亜臨界圧ボイラの建設を行い総発電設備容量は 5,000MW となった。
当初のボイラの石炭消費量は 341～450g/kWh で、その後、省エネルギーを強力に推進し、運転管理技術等の向上により 1995 年で 321～334 g/kWh となり 3.85～5.01%の出力増となった。
国際電力公司となった後、同様な 11 台のボイラの石炭消費量は国際平均の 412 g/kWhに対して 331 g/kWh という高レベルのものとなった。また総設備容量も 9,050MW となったが、その 98%が海外からの輸入機器であった。
その後 600MW 級から 1,000MW 級の国産臨界圧ボイラの開発により 2006 年には設備
容量は 39,770MW と飛躍的に大きくなってきている。
高効率大型ボイラの建設が進み、また 100MW 以下の小型ボイラの廃止により 115 基のボイラの設備容量別構成において 600MW 以上が 32%（12,920MW）、300MW 級が61%（24,420MW）、200MW 級以下が 6%（2,430MW）となった。
継続的にボイラの省エネは進められており、従前のロシア製や国産の 300MW 級ボイ
ラ・タービンについてもフローの見直しやタービンローターの交換等、効率向上に効果をあげてきている。空気予熱器のシール改善、集塵技術の向上、燃焼空気ダンパー
管理技術等を含めた種々の運転管理技術の適用をはじめとして、216 種の省エネに繋がる技術改善が 2006 年導入され効果が発揮されている。
最新の国産の 600MW 超臨界圧ボイラではボイラ効率 93.3%、石炭消費量は 297g/kWhとなっている。
また国産 1,000MW 超々臨界圧ボイラでは、高効率の FGD、低 NOx バーナー、ESP
や冷却用海水処理装置等が付加され、石炭消費量 298 g/kWh となった。

⑦ 第 6 セッション Coal Supply Outlook 石炭供給展望
議 長 1 ： Mr. Restituto G. Taganas, Jr., OIC-Assistant Director, Energy Resource
Development Bureau, Deparment of Energy(DOE), (Philippines)
エネルギー省 エネルギー資源開発局 担当部長 レストウト・タガナス氏（フィリピン）講演 1
Coal Demand and Supply and Policy of Coal Industry in China
中国における石炭需給と石炭産業政策
Ms. Lu Xiaoyan, Director of Research and Consultation,
Information Center, China Coal Sales and Transportation
Association(CCSTSA) (PR China)(author: Mr. Hao Xiangbin, Deputy-General, Information Center,
China Coal Sales and Transportation Association)
中国煤炭販売輸送協会 情報センター 研究諮詢部部長 ルー・シャオヤン氏（中国）（著者；中国煤炭販売輸送協会 情報センター 副所長 ハオ・シャンビン氏）
発電用を中心とする石炭の需要増


中国の石炭消費は近年増加が続いており、2001 年には約 14 億トンだったものが、2007 年には約 26 億トン、2010 年には約 31 億トンになると予想されている。



石炭消費の中心となる産業は、主として、電力、鉄鋼、建材、化学の 4 大産業であるが、中でも電力が最も大きく、2001 年には、電力用石炭消費は約 6 億トンで全体の45％だったが、2010 年には約 18 億トンで全体の 59％になると予想されている。



石炭需要を牽引する 4 大要因は、①都市の発展に伴う住宅関連需要の増加、②農村地帯における農業所得及び工場立地に伴う給与所得の増加、③地域間を結ぶ
交通インフラ整備による経済活動区域の拡大、④石油高騰に伴う石炭液化等の必要性増大であり、この結果、産業用需要の増加及び生活水準の向上に伴う電力需要の増加により、石炭需要が今後とも増大していくと予想される。



一方で、今後、石炭の需要を抑制する要因として考えられるのは、①構造調整と生産性向上による GDP 一単位あたりのエネルギー消費の減少、②政府のエネルギー
多少費製品輸出抑制策、③省エネ技術の進歩、の 3 つ。

石炭供給能力と石炭市場の状況


中国の石炭需給の状況は鉄道の輸送能力と相関関係にあり、2004 年には輸送力不足のため需給がタイトになったが、2005 年には輸送力増強により事態は改善した。
2006 年には輸送力増強の規模が小さかったため需給がタイト化したが、2007 には増強によりバランスのとれる状態となった。

2010 年にかけて、特に山西省、陝西省、内蒙古、寧夏において鉄道の輸送力増強が計画されている。

石炭産業整備目標
2010 年までに生産性が低く安全対策が不充分な小規模炭鉱を閉鎖または整理統合し、優良な炭鉱と大型の企業集団を育成し、13 箇所の大規模な石炭生産基地を
設置する。



トンあたり 20～30 元の安全対策費を徴収する。また課税を強化し、環境対策に充
当する。

講演 2
Coal Supply Outlook in Australia
豪州における石炭供給展望
Ms. Louise Tamaschke, Assistant Manager, Coal Policy Section,
Resources Division, Department of Industry, Tourism andResources (DITR) (Australia)
産業観光資源省 資源部石炭政策課 課長補佐 ルイス・タマシュケ氏（豪州）
豪州は世界の石炭市場の 30％を占める最大の供給国であり、石炭は最大の輸出品で、現在、生産量 3.3 億トンの 74％の 2.4 億トンを輸出。中国の石炭輸出が減少傾向にある中、豪州の石炭輸出は一貫して増加する見込み。
炭鉱開発プロジェクトについては、2007 年 4 月時点で、Dawson（5.7 百万トン）、Lake Lindsay（4 百万トン）、Clermont（12 百万トン）、Bulga UG（6-8 百万トン）、Wambo UG（3 百万トン）、Glendell（2 百万トン）が確定している。
港湾の設備能力も増強される予定で、2007 年に比べ 2012 年時点で予想される能力は、Port Waratah Coal Service：120（←102）Mtpa、New Castle Coal Infrastructure Group: 30（←0）Mtpa、Port Kembla：16（←16）Mtpa、Abbot Point：50（←21）Mtpa、Brisbane：5（←5）Mtpa、Dalrymple Bay：85（←68）Mtpa、Hay Point：44（←44）Mtpa、Gladstone：85（←68）Mtpa、[合計：419（←324）Mtpa]となっている。
豪州は電力の 80％を石炭に依存しており電力需要の伸びも著しい。また世界の温室効
果ガスの 1.3%が豪州の石炭によるもの。石炭を、環境に配慮した持続可能な形で利用するには CCS を含む低排出型技術が必要であるため、豪州は産官学の協力により海外と連携して開発に取り組んでいる。
温室効果ガス削減のため、豪州政府は COAL21 計画を推進中。第一段階は 2015 年まででCCS を含む基礎技術の開発、以降は商業化に向けた開発が進められる。豪州石炭業界は 10
億ドルの COAL21 基金を創設し研究開発を支援している。

豪州が取り組んでいる低排出技術は、CO2 貯蔵、酸素燃焼、燃焼後排ガス等除去、石炭ガス
化、CCS、最新式選炭、褐炭脱水等。
地球温暖化問題について、豪州政府は、1992 年気候変動枠組条約に署名、1997 年専門機
関 AGO を設立、再生可能エネルギーの目標を導入し京都議定書に相応する自国の削減目標を策定。2003 年 CO2 隔離のための Carbon Sequestration Leadership Forum 設立に加わる。
2004 年エネルギー白書で炭素について将来制約が強まることに伴うエネルギー政策と安全保障の包括的戦略を明記（Solar Cities、Low Emissions Technology Demonstration、Renewable Energy Development Initiative、CCS、エネルギー市場の構造改革、バイオ燃料等の支援策等）。2006 年、Asia Pacific Partnership on Clean Development 設立に加わる。2007
年中国との間で CCT 関連組織を設立、2012 年までに排出権取引開始を決定、APEC シドニ
ー宣言、Clean Energy Target 設定。1996 年以来 35 億ドル以上の関連支出をコミット。
豪州の排出権取引案（Australia Emissions Trading Design）：Cap and Trade system による。国内外の情勢変化に応じ適宜調整。排出量と吸収量（排出量全体の 70%）を可能な範囲で最大限カバー。炭素価格により不相応な損害を蒙る企業へ定額の補償金を支払い排出可能量を割り当てるシステム。
Clean Energy Target：2020 年までに 3 万 GWh のクリーンエネルギー（1MWh 当り CO2 が 200kg
未満)の生産を目指す。
本年 9 月のシドニーでの APEC 首脳会議で、各国は実効性ある 2013 年以降の国際的気候変動枠組への道を開くため、長期共通目標について取り組むことに合意した。気候変動枠組条約の主要なプレーヤーが初めて国連での交渉の膠着状態を打開するために排出の共通目標について取り上げた意義は大きい。
豪州の石炭産業は強力であり、アジア太平洋地域の需要増加に的を絞った戦略を持っている。豪州は、現在のボトルネックを解決し、アジア太平洋の中長期的な需要増に対応するため、生産とインフラの設備能力を拡張しつつある。また、低排出技術の開発・実証・普及について
中心的な貢献を行っており、APEC 及び他の国際フォーラムを通じて、低排出技術の国際的な開発等を支援している。

講演 3
Coal Supply Outlook in Indonesia
インドネシアにおける石炭供給展望
Dr. Ir. Sukma Saleh Hasibuan, Director, Directorate of Mineral,
Coal & Geothermal Program Supervision,
Ministry of Energy and Mineral Resources (Indonesia)
エネルギー・鉱物資源省 鉱物・石炭・地熱管理局部長
スクマ・ハシバーン博士（インドネシア）

インドネシアは世界最大の一般炭輸出国で、炭鉱は主にスマトラとカリマンタンに集中し、確認埋蔵量は 2006 年時点で 67 億トンである。炭種は、褐炭(58.6%)、亜瀝青炭(26.6%)、瀝青炭
(24%)、無煙炭(0.4%)で、亜瀝青炭は輸出の中心となっている。
インドネシア経済を支える主要輸出品は石油であるが、約 10 年で枯渇し 2015 年以前に石油輸入国となることが予想されるので、エネルギー安全保障上石油からのシフトが進められており、石炭の役割は重要である。経済成長に伴い、石炭の国内需要が増加する一方、アジア各国の経済が急速に成長していること及びインドネシア炭に競争力があることにより輸出需要も増加している。
インドネシアのエネルギー政策は、1945 年の憲法に基づく国家総合開発計画に沿って策定されており、エネルギーのベストミックス、エネルギーの開発、国内向けおよび輸出向けへの配分、における最適化を目指してる。
政府は 2004 年に国家石炭政策 NCP（National Coal Policy）を策定し、2005 年から 2025 年までの石炭の管理、採掘、利用、開発、等について指針を定めている。
NCP では、石炭を輸出用戦略物資と位置付けるとともに、海外からの炭鉱開発投資の拡大も重視している。また、中央と地方、官と民の役割を定めている。
インドネシアの 2005 年の石炭生産量は 1.43 億トンであったが、2006 年には 1.93 億トンとなった。生産量増加の主要因は輸出需要の増で、2005 年に 92.79 百万トンであった輸出量は2006 年には 1.48 億トンとなった。輸出先の約 60%が東アジア（日本、韓国、台湾、香港）、10％弱が ASEAN 諸国、約 15%がヨーロッパであったが、今後、アジア太平洋地域への輸出が中心になると思われる。
国内エネルギー供給における石炭の比率は、2001 年には 13.1%であったが、2005 年には15.7%となった。最大の需要先は電力で、次いでセメント、他に製造業、金属、製紙、繊維、等の産業となっている。
石油と天然ガスの埋蔵量減少と大規模な新規炭鉱開発に伴って政府が打ち出した石炭火力重視の方針により、発電用石炭の需要は 2010 年には 72.3 百万トン、2015 年には 90 百万ト
ン、2025 年には 200 百万トンとなる見込みであるが、今後の需要増に見合う石炭の増産については可能と考えられる。
石炭供給確保策として、政府は、今後、低品位炭、坑内掘炭鉱、遠隔地の炭鉱の開発への投資について、インセンティブを付与することを計画している。
地方自治体への許認可権の権限委譲も進められている。
炭鉱の新規開発や規模拡大には、探査・採掘等に高度の技術と多額の資本を要しリスクを伴うため、国内外からの投資が必要であるが、いまだに低調である。
至急対応を要する課題としては、税制、権益、地域間対立、違法採掘、林業との紛争、資本の引き揚げ、等が挙げられる。多くは法制の不備によるもので、投資家に不安感を与えている。

政府は上記の問題の解決のため、暫定的な法的措置を講じるとともに、新鉱業石炭法の成立に向け努力している。新鉱業石炭法の施行により、投資環境の整備、中央･地方の権限の明
確化、持続可能な発展の原則の採用、国民の福祉の重視、等が進み、投資家の信頼を回復
して、インドネシアの石炭産業がさらに発展することが期待される。
議長 2：Mr. Hiew Char Loong, Senior Executive (Logistics), TNB Fuel Services Sdn
Bhd (Malaysia)
TNB 燃料公社 上級職（ロジ担当） ヒュー・ローン・チャー氏（マレーシア）

講演 4
Coal Supply Outlook in Russia
ロシアにおける石炭供給展望
Mr. Dmitory Sokolov, International Researcher,
Center for Energy Research, Northeast Asia (CERNA),
Korea Energy Economics Institute (KEEI) (Korea)
Secondered from Energy Systems Institute (ESI),
Siberian Branch of the Russian Academy of Science (Russia) Co-authered with Prof.
Boris Saneev, Deputy Director, and Dr. Alexander Sokolov, Head of Laboratory ofEnergy Systems Institute (ESI), Siberian Branch of the Russian Academy of Science(Russia)
ロシア科学アカデミーシベリア支部 エネルギーシステム研究所から出向
韓国エネルギー研究所 北東アジアエネルギー研究センター 国際研究員 ドミトリー・ソコロフ氏（ロシア）
共著；ロシア科学アカデミーシベリア支部 エネルギーシステム研究所副所長 ボリス・サネーフ
教授・同研究所ラボ担当部長 アレキサンダー・ソコロフ教授
ロシアのエネルギー産業の 1990 年から 2006 年までの生産の動向を見ると、ソ連解体後一時落ち込んだが、その後は着実に増加している。石炭の生産は 1990 年に 3 億 9,500 万トンだったものが 2000 年には 2 億 5,800 万トンにまで低下したが、2006 年には 3 億 900 万トンとなった。
2006 年のロシアの一次エネルギー生産に占める石炭の比率は約 12％であった（石油は約38％、天然ガスは 44％）。
エネルギーはロシアの重要な輸出品であり、2005 年には全体の約 6 割を占めた。石炭の輸出量の伸びは石油、ガス、電力に比較して大きく、1990 年に 4,200 万トンであったものが 2006
年には 8,740 万トンまで倍増した。

2006 年 1 月時点のロシアの石炭埋蔵量と潜在資源量は、合わせて 4 兆 7,700 億トンとなっている。
ロシアには 22 の炭田と 1,700 の鉱床があり、地域別の生産能力は国土の中央部で 80％、東部と西部でそれぞれ 10％となっている。操業中の石炭企業は 240 あり、総生産能力は年間 3
億 2,460 万トン、うち 143 は露天掘りである。選炭工場は４１ある。
2006 年の実際の生産量は 3 億 900 万トンで、うちハードコールが 2 億 3,400 万トン、褐炭が7,480 万トンであった。
2006 年の国内供給の用途別比率は、電力が 48.9%、コークスが 19.9%、生活及び商業部門が14.6％、となっている。2005 年の輸出先の比率は、中東 31%、西ヨーロッパ 29%、アジア太平洋地域 17%、旧ソ連諸国 14%、東ヨーロッパ 9%、となっている。
2001 年以降のロシアの石炭価格の推移を見ると、上昇が続いているが、天然ガスと比較すると 2005 年までは石炭の価格の方が高かったものの、以降 2015 年までの予想では、天然ガスが高くなり高騰が続く反面、石炭はわずかな上昇に留まると思われる（2015 年：天然ガス
94US$/t、石炭 47US$/t）。
ロシアの石炭産業の主要な問題点は以下の通り。


ロシアのエネルギーバランスにおける石炭のシェアが小さいこと



国内消費における褐炭のシェアが大きいこと



採掘した石炭の質が劣化しやすいこと



石炭の採掘に伴い環境に悪影響が生じていること



新技術の導入が遅れていること



鉄道運賃が高く、港湾インフラ整備が不十分であること



石炭処理･加工の技術レベルが低いこと

戦略的な目標と課題は


ロシアの産業・経済と国民に対し、良質の燃料と加工品を安定供給すること

エネルギー市場において他の燃料との競争力を維持すること

環境基準に適合した最新の科学技術に基づき石炭産業が安全で安定した発展を遂げること。

ロシアの石炭の、2030 年の予想生産量は、合計 3 億 5,360 万トン。
また、2030 年の予想国内需要量は、合計で 2 億 5,800 万トン、輸出量は、約 104 万トンと予想
される。

講演 5
Coal Supply Outlook in Vietnam
ベトナムにおける石炭供給展望
Dr. Kieu Kim Truc, Manager, International Relation Business
Department, Institute for Mining Science and Technology(IMSAT), VINACOMIN Group (Vietnam)
VINACOMIN グループ 鉱山科学技術研究所 国際部課長
キュー・キム・チョク博士（ベトナム）
ベトナムの面積は約 33 万平方キロ、人口は約 85 百万人であるが、近年、市場経済の導入により、GDP 成長率は 2000 年から 2005 年の間 7.5％、2006 年 8.2％と急速に伸びており、GDPは 2006 年には 484 億ドルとなり、今後も 2007 年 8.5％、2008 年 9.2％と高度成長が継続すると予想されている。石炭の需要も 2025 年まで毎年 11％の率で急速に増加していくと見込まれる。
ベトナムの石炭の確認埋蔵量は合計約 60 億トンで、炭種ではカロリーが高く硫黄分等の少ない無煙炭が多く、亜瀝青炭や褐炭、脂肪炭も産出される。紅河デルタに大規模な鉱床があると見られているが、地下水が多くて地質がもろく地表は都市部なので開発が難しい。また、他にも大陸棚等も含めかなりの埋蔵量があると想定されているが、本格的な探査が必要である。
ベトナムの石炭産業は 1840 年に始まり、現在は VINACOMIN（ベトナム国営石炭鉱物企業グループ）が、石炭の探査・採掘の他、関連する機器の製造、港湾関係業務、セメント製造等を総合的に実施している。近年石炭の生産量は急増しており、2006 年に 3,800 万トンとなったが、2015 年には 5,700 万トンになると予想され、2025 年まで年 19％で増加が続くと見込まれる。
石炭の国内需要は急増しており、2005 年に 1,500 万トンだったものが 2025 年には 1 億 1,800
万トンとなる見込みであるが、生産が追いついていないのが実態である。輸出も 2001 年には約 400 万トンだったものが 2006 年には約 2,200 万トンと増加しており、2015 年以降は石炭が不足する事態となり輸出が減り輸入が増える。もし生産が増えなければ、2020 年以降ベトナム
は石炭輸入国となり、2025 年時点には 6,000 万トンの輸入が必要と予測される。
国内需要の中心は電力（2006 年時点で 1,250MW）であり、次いでセメントとなっている。
VINACOMIN も発電事業を行っており、運転中の石炭火力発電所が 2 箇所(計 220MW)、建設中または計画中が 10 箇所（計 5,620MW）ある。
石炭産業の堅実な発展および高効率化と環境保護のため、以下の施策が考えられている。
石炭開発マスタープラン（2015～2025 年）の策定（石炭産業が国家経済の目的に沿って持続的に発展することを目的として、炭鉱、選炭場、積出港、鉄道、エネルギー･水供給設備、通信等、各生産部門別の計画が定められており、現在、政府が最終案を審査中である。プランに沿って、資金調達、国営企業の民営化、内外からの投資促進、予算配分、人材養成、インフラ整備、組織と管理の整備等が行われる）。
新規炭鉱開発のための地質調査（2020 年完了目途に紅河デルタ等の鉱床の探査を行う）。

2015 年以降、露天掘りより坑内掘りが増えることに伴う坑内掘りの機械化、及び露天掘り坑の深堀りと連結・拡張等。
選炭工場の改善と新増設、ボタの再利用等石炭の完全な活用。
法制と管理体制の整備（市場メカニズムの導入、補助金の廃止、減税、CCT・省エネ・環境保護・研究開発・国際協力に関する啓蒙、関連する法律、技術基準、指針等の制定）。
環境保護（世界遺産ハロン湾の汚染対策のため利益の１％の環境基金への寄付、採掘跡地の復旧、等）
ベトナムの石炭の供給量には限度があるが国内需要は急増している。ベトナム政府とVINACOMIN は、石炭の増産と環境にやさしい石炭利用のための対策に着手したが、技術と資金が充分ではないため、世界の石炭関係機関と協力することにより、アジア太平洋地域のエネルギー需給の安定に貢献していきたい。

講演 6
Indonesian Coal Development
インドネシアの石炭開発
Dr. Hadi Nursarya, Head, Affiliation Division,
Head of Agency for Research and Development,
Ministry of Energy and Mineral Resources (Indonesia)
エネルギー・鉱物資源省 調査開発庁部長 調整部部長
ハジ・ヌサルヤ博士（インドネシア）
インドネシアにおいては、石炭は少なくとも 2025 年までの間、中心的なエネルギー源と位置付けられている。
2005 年のエネルギー構成は、①石油約 62%、②ガス約 29%、③石炭約 15%、④水力約 3%、⑤
地熱約 1%だったが、この比率を 2025 年には、①石炭約 33%、②ガス約 30%、③石油約 20%、
④バイオ約 5%、⑤地熱約 5%、⑥太陽光・風力等約 5%、⑦液化石炭 2%とすることが目標とされている。
インドネシアの石炭鉱床のうち、約 59％が褐炭、約 27％が亜瀝青炭、約 14％が瀝青炭、となっている。
生産量は、2006 年には 1.93 億トンで、この内、1.45 億トンが輸出され、4,800 万トンが国内で消費された。今後 2025 年には、生産量は 3.7 億トンまで増加するが、国内消費が電力用を中心に 2.2 億トンまで増加するため、輸出は 1.5 億トンに留まると予想される。
インドネシアでは、石油依存度が低下しつつある一方で石炭の利用が増加し、多数の石炭火力発電所の建設が計画されている。
石炭の需要増に対応し、インドネシアでは、低品位炭改質や石炭液化・ガス化等について、商業化を目指した研究開発が進められている。

インドネシア政府は現在、新鉱業石炭法の制定に向けて最終調整中であるが、持続可能な開発の方針を明確にし、国民の幸福を最優先としている。具体的には、採掘の許認可を 1 種類にすること、外国の炭鉱会社は国営の炭鉱会社と契約すること、探査と採掘の許認可を簡素化すること、鉱区は入札で決定すること、住民の福祉を念頭に地域開発を重視すること、等が盛り込まれている。この法律の施行により、投資環境が改善され、中央官庁の許認可手続
きも整理されると期待されるので、インドネシアの石炭開発はさらに進展すると見込まれる。

⑧ 第 7 セッション Energy and Water Saving in Coal-fired Power Plant
石炭火力発電所における省エネ・省水議長 1：Mr. Zhao Yi, Vice President, Thermal Power Research Institute (TPRI) (PRChina)
西安熱工研究院 副院長 ザオ・イー氏（中国）

講演 1Application of Low Temperature Sea Water Desaltion andCogeneration of Water and Power
低温海水淡水化適用と発電と水の生産
Ms. Zhang Jiangli, Senior Engineer, Beijing Guohua Corporation,
Co-authored with Mr. Chen Yinbiao, Deputy Chief Engineer,
Bijing Guohua Corporation (PR China)
北京国貨有限公司 上級技師 ジャン・ジャングリ氏（中国）
共著；北京国貨有限公司 副主任技師 チェン・ユンビオ氏
火力発電所で使用する冷却水等の水の確保が困難な条件において、SWRO、MSF、MED、TVC 等、様々な海水の淡水化技術がある。
今回、国貨発電会社が研究開発採用した低温 MED（TVC-MED）を紹介する。低温 MED 法
は水加熱温度が通常の MED の 100～120℃と比較して 70℃の低温加熱で淡水化するもので省エネに大きく寄与する。蒸発器においても 80℃以下の低温蒸気温度を採用しているため、各機器の腐食等も少なくて済む。淡水化度は 10mg/L、淡水に必要な電気及び熱エネルギーは～5.0kWh/m3 で他の淡水化方法に比較しても経済的である。低温とシステムがシンプルであるため、各機器に高耐腐食性の素材を必要としないことや、操業が簡単であるため、建設費や運転管理費についても他方法より効果がある。発電所においては淡水化に必要な熱エネルギーは蒸気タービンの低圧廃熱を利用する。発電所における使用水を全て本淡水化装置で賄う場合、200～300 億 m3 の河川水等が節約することが出来、民生使用の需要に充てる

ことが可能となる。国貨幣・黄貨石炭火力発電所（2×600MW）では初めて淡水化システム導入プロジェクトが実施された。
2 基の第一期淡水化装置は 2006 年 5 月 14 日に稼働し、西安熱工研究院により単機で 10,000
トン/日の淡水、塩分濃度 5 mg/L 以下、消費動力 1.0 kWh/m3 が確認された。
今後も石炭火力発電所の立地を考えるに地域条件に適し、貴重な河川水を使用することなく海水を淡水化、使用することにより、地域と共生した火力発電の建設が必要であり、本技術の拡大を期待している。
Q&A
Q: ボイラ供給用の淡水化に係るコストをどう考えているか。
A: 現状 6～7RMB を適正なコストと考えているが、導入効果や更なる技術開発や効率向上によりもっと低いコストも可能と考えている。

講演 2
Low-Risk and High-Return TIFItm Technology for Energy
Efficiency Improvement and Pollution Reduction
エネルギー効率向上と低公害のための低リスク高リターンのTIFItm 技術
Dr. Linda Lin, Vice President, Asia/Pacific, Fuel Tech (USA)フュエルテック社 アジア太平洋地区担当副社長
リンダ・リン博士（中国）中国における石炭ボイラ燃焼技術は高揮発分、低灰分・硫黄分炭の利用から低品位の高灰分炭の利用に拡大しなければならない。併せて発電所の高効率化による省エネルギーと CO2の排出を含めた環境対応への取組みが、2007 年米国を抜いて中国が CO2 排出大国となることからも第 11 次５ヵ年計画で強く求められている。
石炭火力発電所のボイラに起因するトラブルは全体の 56%で、ボイラトラブルのうち 64.2%がボ
イラチューブに関係するトラブルである。溶接や材料にまつわるものを除き、トラブルの殆どが残渣やスラッギング、低温・高温腐食、損耗によるものである。伝熱部分のトラブルは修理やメンテナンスに多額の費用を要する。具体的にはスラッギングの多い部分として、ボイラ内部の過熱器及びその管寄せ部分、輻射伝熱面と再熱器部分、水冷壁部、バーナー近辺、炉底ス
ロープ部分等がある。症状としては、スラグ付着による伝熱交率の減少、クリンカの崩落によるチューブ破損、炉出口の高温化、スートブローの頻度向上によるチューブの磨耗があり、それらトラブルによるボイラ停止や修理、また、予測できないスラグの落下によるボイラ底部の破損によるボイラ緊急停止やその修理やメンテナンスにより莫大なコストを損失している。
Fuel Tech 社の TIFI 技術は、各種のボイラに適用し、設備投資を要しない火力発電所の安定操業に資する技術である。火炉の 3D モデリングを用い正確な状況の把握や、炭種の影響等

が確認され、石炭吹き込み方法の検討や改善により、スラッギング等の問題等の解決を図り、ボイラの最適化を図るもので、これまで約 100 件の成功例を持つ。結果として、SO3 の発生減
少や、再熱器での圧力差の減少、主蒸気温度の向上、再熱器蒸気温度の向上等、熱効率の向上が見られるほか、付着スラグの減少等、様々なメリットが見られ、プラント総合効率の向上
や信頼性の向上による稼働率が向上する。500MW 級ユニットの場合、効率向上により 4.1 百万ドルのコスト低減が可能となった。

講演 3
Evaluation of Energy Consumption and Analysis of Energy
Saving Potentional in Coal-fired Power Plants
石炭火力発電所のエネルギー消費評価と省エネルギー可能性解析
Mr. Yu Xinying, Deputy Director, Utility Technical Supervision.
Thermal Power Research Institute (TPRI) (PR China)
西安熱工研究院 公益事業技術部 副部長 ユー・シンユン氏（中国）2006 年末までに中国において操業を開始した超臨界圧ボイラ、タービンユニットは計 38 基、本年度は 50 基を超えた。しかしながら実操業においてユニットの設計仕様である石炭消費量を満足したユニットは 7 基しかない。
また、蒸気タービンの評価試験において設計値をクリアしたものは 21 基である。
その他、色々な事由により計画にないユニット停止を余儀なくされたのが 15 基もある。
近年大型のボイラ・タービンユニットが数多く建設されているが、なぜ設計値を満足できないのか、どこに問題があるのか、また満足できるようにするには、どのようにすべきかを考えなくてはならない。－経済性、環境性能を高めていくためには重要な課題である。
現状、新規稼働ユニットのエネルギー消費は稼働実績と設計値にはボイラ効率及びタービン
熱消費率ともに大きな隔たりがある。症状として、タービンの負荷率が低いことによる効率低下、系統内でのバルブやシール面から漏れが多いことによる熱及び蒸気の損失、炭質の変動に起因する不安定燃焼条件下での運転で未燃炭素量が多いことなどがある。
対策としては蒸気タービン通流部分、及びシール部分のクリアランス調整により改善が可能である。
また水量や水質・水温の影響によるクーリングタワーユニットの性能の問題による熱効率の低下も見られる。その他、オペレーターの習熟不足による主蒸気パラメーターの調整不足もある。
また、もともと補機を選択する際に適性に機種が選択されておらず、要求スペックに対して設備機能が大きすぎたりしている場合もある。
これらの要因として早すぎるユニット建設の影で、システム設計や製造時の問題、設置の際の調整等の最適化がおざなりにされていることに尽きる。

日本の石炭火力発電所のような緻密な最適化が高効率ユニット出力を生むことを踏まえ、新規ユニットの総合的評価・検討が望まれる。

講演 4Renovation of Coal-Fired Power Plants
石炭火力発電所のリノベーション
Dr. Tohmei Takekawa, General Manager, Business Promotion
Department, Japan Coal Energy Center (JCOAL) (日本)
(co-authored with Mr. Li YuSheng and Mr. Hao Ji Hong of China
Electricity Council)
財）石炭エネルギーセンター 事業化推進部長 竹川 東明 氏
共著；中電連 ルー・ユシェン氏・ハオ・ジホン氏
中国における石炭利用量の半数以上が石炭火力発電所に利用されていることより、利用効率
及び環境調和型石炭利用は省エネルギー、及び環境保全に対して重要な課題である。日本
では優れた操業管理・メンテナンス技術で石炭火力発電所を 40 年間も効率 40%を維持するなどしている。―今回 JCOAL が実施しようとしているのはこれらの日本の技術を中国に診断・適用し高効率化・環境性能向上に寄与しビジネスベースでの協力の向上に資するものである。
日本の石炭火力発電所は SOx、NOx、粉塵等、設備改良を重ね、最近設置のプラントでは超々臨界圧ボイラユニットと環境装置の導入により世界のトップレベルとなっている。また、日
本全体の火力発電効率も 40%を維持している。
これらの技術を海外に適用した実績として、例えば中国においては、診断により、ボイラ伝熱面の洗浄、1 次過熱器スートブローの実施、節炭器のスートブロワの設置、蒸気タービンの高圧側シールフィン取替えや動静翼の新製等により、効率改善が 4.4%、石炭消費量にして－88k トン/年、CO2 の排出削減にして－212k トン CO2/年の実績例等がある。中国電力企業連合会と国際協力銀行及び JCOAL の三社が MOU を 2007 年 4 月に締結し、中国の火力機発電所調査の実施や中国側の日本訪問等、診断・改善の実施に向けて作業が進められている。
財政支援スキームとして、国際協力銀行が中国側火力発電所に対して診断・改善にかかる資金を融資し、その結果として効率向上により発生したカーボンクレジットを日側がアレンジすることが出来ることを考えている。2007 年度に試行的診断を行ったうえで、実施プラントの絞込みを行い、改善工事を実施する予定である。

講演 5
Status of Water Saving and Key Analysis in Chinese Coal-fired
Power
中国の石炭火力発電所における省水技術の現状
Mr. Yang Baohong, Director, Water Treatment Technology Dept.,
Thermal Power Research Institute (TPRI) (PR China)
西安熱工研究院 水力技術部 部長 ヤン・バオ氏（中国）中国における石炭火力発電所でのボイラ蒸気用水や冷却水等の用水は貴重で、特に内陸部の発電所では使用水量の節減は重要な課題である。
発電所における 2006 年の単位出力当たりの水使用量は 1.5～5.0 kg／kW で、水源別では、
地下水、河川水、再生水等があり、地下水の枯渇問題や近年火力発電所の建設増により、使用水増に対して、供給源の確保が困難になりつつある。
この対策には、発電所で使用する用水使用量の低減と使用水の循環再利用の促進が重要となる。用水の循環再利用を行う場合、水質のチェックと再利用のための浄化プロセスとその設備、腐食への影響とコンデンサチューブの材質の検討、再循環による残渣分の凝縮対策を考慮する必要がある。使用処理前の Ca(HCO3)の各発電所の含有量を調査した結果、0～5mmol/L であった。－また、コンデンサチューブの材質は 72%が銅合金製、23%がステンレス製、鉄製が 5%であり、使用水質とチューブ材質の適用化を図る必要がある。
プラント全体の用水使用節減において、煤塵抑制において乾式集塵方式を採用しているのは 35.7%である。プラント排水の発生やその処理、再利用化も課題となる。排水処理設備の多くが水再循環方式でなく処理後、域外排出となっている構造上の問題のほか、高度な技術を使用した排水処理施設そのものの技術上とその設備への投資等問題を抱えている。
用水の利用にあたってはシステム的に要求水質の高いほうから低いほうに再利用し効率を向上させることが肝要であり、またプラントの総合効率からくる各設備の適用化も重要である。

議長 2：Mr. Sun Rui, Chief Engineer, China Power Engineering Consulting Group
Corporation (PR China)
中国電力工程顧問集団公司 主幹技師 スン・ルイ氏（中国）講演 6Control of PM from coal combustion
排煙処理技術について
Professor Yao Qiang, Head, Department of ThermalEngineering, Tsinghua University,
Director, National Engineering Research Center of Industrial
Boiler and Clean Combustion Technology of Domestic Coal
(PR China)
清華大学 発電技術部 部長 ・国立国内炭専用産業ボイラ・燃焼技術研究所 部長
ヤオ・キン教授
都市部での浮遊粒子状物質汚染問題の多くが石炭燃焼の影響によるものと考えられている。
北京での浮遊粒子状物質汚染も燃焼により発生排出された煤塵が新しい浮遊粒子状物質の形態を形成していることが大気中ダストの分布特性や成分構成により推察される。
浮遊粒子状物質のサンプリングには米国 EPA17 のアンダーソンスタックインパクターを用いて発電所から排出されているフライアッシュを捕捉するもので、8 種の粒径別に捕捉回収し As、
Pb、Cr、Cd、Ni、Co、Cu、Zn が検出・分析が可能である。
石炭灰はその燃焼方法により特色があり、微粉炭焚きボイラは顕微鏡観察によると球状になっているのに対して、流動床ボイラは、石炭と流動媒体が結合しフロックのような集隗状となっている。
また、粒径分布については微粉炭焚きはほぼ 10μm を中心に集中しているのに対して、流動床燃焼は 10μm 以下で広く分布しているのが特徴である。
微量有害元素である水銀による汚染を見ると、電気集塵機装置の前後のガス組成の違いより、入口では Hg0 が殆どに対して、出口では総量も減少し、Hg0 が減少し Hg2+が増加していることが分かったことより捕捉されるフライアッシュの影響を受けていることが分かる。
生成するアッシュの特性はボイラ内部の燃焼条件によるもので各実験により、粒度・質量分布が異なることより、電気集塵機出口の組成を検討しボイラの燃焼条件のパラメータを把握することにより、浮遊粒子状物質汚染問題の要因となる組成のフライアッシュ発生を抑制することが可能であり、新しい手法と管理体制の構築が必要である。
Q&A
Q: 水銀の捕集についてはどうか。
A: FGD や SCR の経路の中でフライアッシュに吸着されることは分かっている。また、SCR の前後で酸化水銀の量が減少変化していることより SCR においても何らかの挙動があることは想像される。しかしこれにより積極的な水銀捕捉を行うものではない。

講演 7
New Technologies for Power Plant Water Conservation
火力発電所における新しい省水技術
Mr. Tom Dendy, Director, Global Market& Application Development, SPX Thermal Equipment& Services (US)SPX 発電設備サービス社 世界市場開発部 部長
トム・デンディ氏（米国）
石炭火力発電での回収蒸気の冷却方法には水消費の少ない空気冷却や水消費が大である
クーリングタワー等、立地条件等により異なるが、一般的には使用水量の逼迫した環境下にあり、特に中国では顕著であろう。
また、設計値のプラント効率を維持するためには、プラントの冷却システムを検討することは重要である。湿式は効率や所内動力消費は小さいがその水処理やメンテナンス費用が大きくなるなど、乾式・湿式ともにそれぞれ特徴がある。
SPX 社では、湿式と乾式の利点部分を多く取り入れるハイブリッド型冷却システム Air2Air を開発した。それは従来のクーリングタワー方式の気体高をやや高くし、下方より吹き上げる冷却
空気の変わりに冷却水を側面より噴霧し、噴霧冷却水と冷却空気により凝縮した純水を部分的に回収するものである。これにより 500MW 級プラントの場合、蒸発器水が 16,000 トン必要に対し、2,000～5,000 トンが清水として回収することが可能である。本システムは実験室レベルのテストを経て 2007 年 10 月よりニューメキシコ州で DOE の補助を受け実用機が稼働している。各部分の操業状態はワイヤレスデータ計測システムが組み込まれ、維持管理も非常に簡便である。本システムは、冷却ファンの必要動力が大きくなるものの、複雑な構造を必要とせず、維持管理もたやすく、湿式と同様な冷却による機器稼働効率が得られ、15～30%の冷却水が節減可能となり、これまで湿式で見られていた発生水蒸気煙を小さくすることが出来るよう
になった。

講演 8
Integrated Strategy for Efficiency, Emissions Reductions andSafety for Coal-fired Power Plants
環境に調和した石炭火力発電
Mr. Brad Radl, President and Chief Technical Officer, Taber
International LLC (US)
タバーインターナショナル社 社長兼技監 ブラッド・ラドル氏（米国）
石炭火力発電所には効率向上に大きく影響する設備システム要素部がある。ハードとシステ
ム管理等のソフトの不適合による効率やコストのロスを生じる場合もあり、システム統合と適合化により設備投資や運転コストを低減させることも可能となる。
現行のボイラーの場合、熱効率を 5%向上させることにより石炭消費量が 360g/kwhr から
342 g/kwhr に、SOx、NOx、その他の有害物資の排出の低減にもなる。
先進的な高効率システム化の障害となっているのは、古い機器によるものや経験・情報不足によるもの、また、オペレーターに起因するもの等がある。NOx の排出低減を行う場合、要素技術としては燃料転換、低 NOx バーナーの適用、過剰空気燃焼やスートブロー方法の適合化等がある。これらの組み合わせにより 40～90%の削減につながる。
実行段階において具体的には、酸素濃度センサー、一酸化炭素センサーの取りつけ、スート
ブローの調整、低 NOx バーナーの採用と個々バーナーへの空気調整を行うこととなる。これ
らを実行することにより、炉出口の排煙温度の低減や炭種の拡大等のメリットも出てくる。機器と運転管理システムの適用化により熱効率が 5%以上の節減が可能となった場合、NOx の排出量削減が 20～80%、5%の CO2 の削減、ボイラ冷却水中の塩素や臭素も除去できる。その他蒸気タービンの能率向上では、タービン内の内部漏れ損失を小さくするため、翼との間隙
を 0.05cm から 0.005cm に精度を向上させることにより、1～3%の蒸気タービンの効率向上が期待できる。
これらの様々な効率向上要素部分をハードと管理ソフトの適合化により、高効率で環境に調和した石炭火力発電所となる。改造にあたっては、数日で改造が済む場合や、蒸気タービンの改造のように高コストを伴うものもあるが、高効率に一番寄与する部分でもある。

講演 9
Problems in Condensate Polishing System of Direct Air-Cooled
Unit and Its Solutions
乾式冷却方式の水凝縮精製に係る問題点と解決
Dr. Tian Wenhua, Thermal Power Research Institute (TPRI) (PRChina)
西安熱工研究院 ティアン・ウェイハ博士（中国）
ボイラ蒸気用水の冷却にあたり乾式が多く中国では使用されている。しかしながらボイラ仕様に基づく冷却後の腹水凝縮水の純水処理が上手く行われていないのが現状であることが我々の調査で分かった。
水の不足している北部の地域では新規に建設を行う大型の発電所は乾式冷却方式を採用することが義務付けられている。
一般的に空冷方式は、水冷方式に比較して、冷却面積が大きく、凝縮水中に腐食生成物が多いため水質管理が難しいとされている。
現在稼働しているプラントの純水処理方法には概ねイオン交換方式である複床式純水法やPowdex 法の２種類が使用されている。

最近の建設プラントの多くが、ろ過吸着力が高く、構造がシンプルで、再生システムや廃液処理が必要ではない Powdex 法が採用されつつあり、現稼働中のプラントでの純水について調査した結果、空冷システムの特徴に対する認識不足があり、鉄分の除去のみにとらわれて
Powdex 法を採用し、脱塩が不十分であり、二酸化珪素分、二酸化炭素分、溶存酸素分が基準値を超えている。また、複床式を採用している発電所では復水凝縮水の温度が高く、特に夏場になると基準温度値を超えその対策により、不純物が純水に混入している。臨界圧蒸気
条件でのボイラでは、亜臨界圧蒸気用水質より厳格な給水管理が求められることより、ボイラ
チューブ等腐食の発生やスケール付着による効率低下等様々なトラブルの発生が危惧される。
これら空冷方式を採用している発電所での復水凝縮水の純水処理方法について、空冷ユニットに係るシステム総括を行い、最適化を図ることが重要である。
また、空冷ユニットの設計や稼働時の技術規範、及びその条件を策定することが必要である。
Powdex 法が除鉄とろ過しか出来ないことを認識し、域内の塩類、不純物、珪素分、二酸化炭
素、溶存酸素分の影響が顕著になる臨界圧蒸気ボイラに対して認識を改めることが必要である。

⑨ 第 8 セッション FBC/ USC/ IGCC/ CCS
議長 1：Professor Yao Qiang, Head, Department of Thermal Engineering, Tsinghua
University Director, National Engineering Research Center of Industrial Boiler andClean Combustion Technology of Domestic Coal (PR China)
清華大学 発電技術部 部長 ヤオ・キン教授
国立国内炭専用産業ボイラ・燃焼技術研究所 部長

講演 1
An Overview of Post-Combustion CO2 Capture at CSIROCSIRO における燃焼後 CO2 回収について
Dr. Paul Feron, CEO Science Leader,
CSIRO Energy Technology, Commonwealth Scientific andIndustrial Research Organization (Australia)
CSIRO エネルギー研究所 科学担当 CEO ポール・フェロン博士（豪州）
IPCC では、温暖化現象は明白であり、20 世紀半ばからの地球規模の平均気温の上昇は人為的な温室効果ガス濃度の上昇によると述べている。その対策としては、ガス転換、原子力、新エネなどがあるが、CCS も重要な項目に挙げられる。

現在、CO2 回収の技術については、発電コストが上昇すること、発電効率が減少すること、発電所規模において CO2 回収の経験がないことが問題となっている。我々が PCC（燃焼後CO2 回収）を推奨するのは、技術的なリスクが小さく、市場に合わせて柔軟な操業が可能で、ゼロエミッションに向けた技術革新の可能性があるためである。
一般的な PCC の問題点は、CO2 回収コストが$30/t と高いこと、温室効果ガスを 85%削減す
ると発電コストが 30～50$/MWh に上昇すること、CO2 を 90%回収すると 20～30%発電効率が下がること、実際の発電規模の経験がないこと、冷却水が多く必要なことなどである。
PCC における回収方法として MEA（モノ・エタノール・アミン）吸着液が使われているが、将来は新溶媒による回収及び新回収システムを目標にしている。
アミンは反応が早く比較的安価であるが、アミンが CO2 を吸収した際に発生するカルバミン酸
塩が高い安定性があり、再燃に多くのエネルギーを必要とする欠点などもある。
現在、瀝青炭、褐炭を使った発電所で、可搬式の PCC パイロットプラントを用いて、アミンベ
ース新溶媒、アンモニアベース新溶媒の試験を行っている。

講演 2
Two-State Dry-fed Entrained Flow Coal Gasifier
乾式給炭二段噴流床石炭ガス化炉の開発
Dr. Xu Shisen, Chief Engineer,
Thermal Power Research Institute (TPRI) (PR China)
西安熱工研究院 主幹技師 シュー・シセン博士（中国）
噴流床ガス化炉は移動床、流動床より高い炭素転換効率がある。
主な噴流床としては、湿式給炭方式の Tex aco、E-Gas、乾式給炭方式の Shell、Prenflo、
GSP などがある。
乾式給炭噴流床ガス化炉は炭素転換効率が高く酸素消費も少ない。
TPRI では石炭ガス化炉の開発を進めている。最初に 1998 年に中国国家電力総公司（SPC）のファンドで 700kg/d 規模の加圧噴流床ガス化炉のベンチスケールの試験を行った。
次に 2004 年に中国国家電力総公司（SPC）と中国科学技術部（MOST）のファンドで36-40t/d 規模のパイロットプラントを建設し国内 13 炭種の試験を行った。
TPRI では 2009 年から 250MW 級の IGCC のガス化炉実証プラントの運転を華能電力天津で開始する予定である（2000t/d）。また、Shilin Chemical Ltd. とガス化炉における1000t/d 級の化学工場の操業を開始する予定である

講演 3
Fluidized Bed Combustion Power Plant Technology by
Low-Grade Coal
低品位炭を使った流動床ボイラ技術
Mr. Yoshiteru Nishie, Advisor to Director (China IPP Business),
International Power Business Department,
Electric Power Development Co., Ltd. (JPOWER) (Japan)
電源開発㈱ 国際事業部 調査役 西江嘉輝氏（日本）
バブリング型流動床ボイラ（BFBC）の利点は、低温燃焼で小型ボイラであっても高い効率をあげるところにある。中国には小規模の発電所が多いため（115MkW）、BFBC に改良することによって高い発電効率を実現することができる。370～390g/kWh を目標としている。
日本において PFBC の技術は 1980 年代と 1990 年代に石油火力発電からの石炭転換によって開発された。2 段燃焼によって 98％以上の燃焼効率をもち、50～100MW 級でも高い発電効率を得ることができる。また、炉内の燃焼温度が 860 度と小さいことから NOX、SOX 発生
量を抑えることができる。改造費用も安い。JPOWER では若松と竹原で改良実績がある。竹原第二は石油火力から BFBC への改良で、世界最大の 300MW の操業実績があった。ボイ
ラ効率 93％、発電効率 38.5%である。
中国では 115MkW の小規模発電所が閉鎖されるであろう。この 10%の 10MkW 分が 1 億トンの低品位炭を使った BFBC に転換されることは CCT につながる。この転換は 100～
300MW 規模の発電所に適応できる。
環境面に関しては 50MW 級で年間 7 万トンの CO2 削減、NOX 発生量の半減、石灰石脱硫による高脱硫率、高集じん率、石炭灰の完全活用などのメリットがある。

講演 4Development

andStatusof

UltraSupercritical

Power

Generation Technology in China
中国における超々臨界発電技術の現状
Mr. Zhu Baotian, Chief Scientist, Thermal Power ResearchInstitute (TPRI) (PR China)
西安熱工研究院 主幹技師 ゾオ・バオティアン氏（中国）中国では 2006 年までに 47 基の SC＆USC ユニットが稼動している。－中国では 1992 年に
華能石洞口(Shidongkou)第二発電所で初めて 600MW 級の SC ユニットを導入した。2004
年には国産 600MW 級 SC ユニットを華能沁北(Qinbei)発電所に導入した。2007 年 8 月中国初の 600MW の USC ユニットが華能営口(Yunkou)発電所に導入された。2006 以降、商業ベースで 1,000MW の USC ユニットが華能玉環(Yuhuan)、華電鄒縣(Zouxian)などに導入され、2007 年 9 月までに中国で 4 基の 1000MW の USC ユニットがある。
世界には 10 機の 1000MW の USC が導入されているが 9 基が日本、1 基がドイツである。
華能玉環(Yuhuan)の 1,000MW の USC ユニットは日本のものより内部圧が高く、ドイツより内部温度が高い。つまり、華能玉環(Yuhuan)の能力は圧力、温度、効率など世界最高の技術である。
中国国家発展改革委員会の第 11 次 5 カ年計画において、大型の SC 用蒸気タービン、大型SC ボイラなどの研究開発、USC の事前 FS が組み込まれている。
また、国家 863 プログラム（USC 火力発電技術）においても華能などの 3 大電力、西安熱工研究院、華東電力設計院などが共同して USC に関するさまざまな研究を実施している。華能玉環(Yuhuan)の 1,000MW プロジェクトもその一つである。
2003 年、中国は USC ユニットの製作に関して国産化を目指し、大連ボイラ工場（日立）、ハ
ルビンボイラ工場（三井バブコック、三菱）、上海ボイラ工場（アルストム）、大連タービン工場（日立）、ハルビンタービン工場（三菱、東芝）、上海タービン工場（シーメンス）にそれぞれ海外の先進技術を導入した。現在では世界レベルの技術に達している。
2007 年 6 月時点で中国国内では 600MW 級 SC ユニット（180 基）、1,000MW USC ユニット（30 基）、660MW USC ユニット（26 基）、600MW USC ユニット（7 基）を建設、製作中である。
2010 年までには世界の USC ユニットの半分は中国で稼動しているものとなるであろう。2020年までには中国の火力発電所の 70%は SC、USC ユニットとなるだろう。SC と USC 技術が今後 30 年間、中国の発電を担うであろう。

講演 5
Analysis of 3-TPD Coal Gasification System in Korea
韓国における 3t/d 石炭ガス化システムの解析
Dr. Hyung Taek Kim, Division of Energy System,
Ajou University (Korea)
亜州大学 エネルギーシステム部教授 ヒュン・テク・キム博士（韓国）韓国における 3t/d 石炭ガス化プラントは TPRI ガス化パイロットプ
ラントと似ている。1994 年に建設された。IGCC に適合した炭種を調べるために中国炭、インドネシア炭など世界中の 90 炭種を使用して、ガス組成、炭素転換率、ガス化効率、灰溶融温度などの試験も実施してきた。そして、それぞれの炭種を石炭の特性によって 4 つに分類別
けをし、アダロ炭、バイドリー炭、大同炭などが IGCC に適合する炭種であることがわかった。
次に 2006 年 12 月に開始したナショナルプロジェクトである 300MW の IGCC 商業化プラン
トについて説明する。2015 年までの 8 年間の事業であり事業費は 8 億ドルである。10～20％の国の補助があり、その他は産業界からの支援である。韓国政府は CO2 削減のために 2012

年までに総発電の 7%を再生エネルギーにすべきと表明しているが、太陽光、風力にしても非常に小さいものであり、IGCC が環境的にも効率的であると考えている。
IGCC プラントは 2012 年に完成する予定である。ただ韓国にはガス化の技術はなく、シェル、GE、コノコフィリップスなどガス化メーカーとライセンス契約を結ぶ必要がある。そこで基本設
計はこれらのメーカーが行うことになり、詳細設計は韓国のメーカーが行うことになると推測する。
このプロジェクトは国家プロジェクトであり、世界最高レベルを目標に、40%を越える発電効率、NOx 排出 20ppm 以下とし、プラントの 90%以上は韓国企業で設計・建設する。8 年間のプロ
ジェクトは 3 つのフェーズに分けられており、第 1 フェーズは設計、第 2 フェーズは建設、そして第 3 フェーズはデモンストレーション操業となる。

議 長 2 ： Dr. Sihyun Lee, Princicpal Researcher, Energy Conversion Research
Department, Clean Energy System Research Center, Korea Institute of Energy
Research (KIER) (Korea)
韓国エネルギー研究所(KIER) エネルギーシステム研究センター エネルギー転換研究部
研究主幹 シヒュン・リー博士（韓国）講演 6
Carbon Capture and Geological Storage Projects in APECAPEC 諸国における炭素固定化技術プロジェクト
Dr. Frank Mourits, Senior Science and Technology Advisor,
Office of Energy R&D. Natural Resources Canada (Canada)
カナダ天然資源総局 エネルギー研究所 上級科学技術アドバイザー
フランク・モーリツ博士（カナダ）
APEC の各首脳はちょうど一カ月前にシドニーで開催された会合において、気候変動を第一検討事項とした。その中で CCS を含むゼロエミッションについても議論された。APEC は世界の中で人口の 41%、一次エネルギー消費の 60%、温室効果ガス排出の 58%を占める。
2002 年に APEC の EGCFE と EWG は包括的目標として CCS イニシアチブを発足させた。
APEC では CCS プロジェクトに関して第 3 フェーズまで終了し、現在は第 4 フェーズを申請中である。
第 1 フェーズ（2004 年 3 月～2005 年 6 月）は日本、ロシアを除くアジア環太平洋地域における地質学的 CO2 貯留ポテンシャル調査。29 箇所の堆積盆地が評価対象となった。その結果、中国において、CO2 排出量が多い地域に近い少なくとも 4 箇所の堆積盆地の存在が明らかになった。また、インドネシア、マレーシアは貯留ポテンシャルが高いが韓国、台湾及びフィリ
ピンは低い。
第 2 フェーズと第 3 フェーズ（2004 年～2007 年）は、研修教材作成とワークショップ実施による APEC 経済区域の CO2 回収と貯留ポテンシャルの認識確立と各国が実施している CCS
プロジェクトの評価と開発であった。
2 日間コースの研修教材を作成し、政府関係者、産業界、大学、一般市民等を対象に韓国、中国、メキシコでワークショップを行った。
研修内容は CCS に関する課題と Weyburn と Sleipner の 2 つのケーススタディーについてである。
Weyburn – Midale プロジェクトについては、非常に商業性のあるプロジェクトである。枯渇しつつある油田に油井から CO2 を入れて、油を回収している（EOR）。現在は 2010 年までの最終フェーズの段階。総事業費は 8 千万ドル。
第 1 フェーズの結果として、Weyburn フィールドは CO2 貯留にとって大きな容器であることがわかった。
EOR 地域において CO2 圧入後、5000 年後にどのくらい移動するかシミュレーションしたとこ
ろ、圧入した CO2 の 27%が移動する結果がでた。18%は水相によって地表に移動し、9%は75 のパターンによって移動することが予想された。
APEC では、第 4 フェーズの実施が正に認証されたところである。
実施内容は中国を含む 2 箇所でのワークショップ開催である。

講演 7
GE’s Gasification & IGCC Technology Application in China
中国における GE のガス化・IGCC 技術
Mr. Jian-Feng Liu, Technical Director,
Application Engineering, China, GE Energy Consulting (US)GE エネルギー社 中国支社 技術開発部 技術担当部長
ジャンフェン・ルイ氏（米国）
IGCC 技術は優れた他の石炭利用技術よりはるかに環境性能が高く天然ガスコンバインドサ
イクル並みである。超臨界圧の微粉炭焚き火力と比較して、NOx33%減、SOx75% 減、PM1040%減、90%以上の水銀除去、プラント使用水量の節減 30%、CO2 の捕集が出来るな
どのメリットがある。
GE は 1948 年から 62 のガス化炉操業の経験を持ち、石炭ガス化は 1978 年から実施している。
GE のガス化炉はシンプルで汎用性が高く、高効率でコスト低減に寄与する他、省水型である
ことより中国の電力・ガス市場に適合する。現在は肥料、1,500～2,000t/d の DME、水素製造が可能で、まもなく、4,000t/d DME 製造プラント、IGCC のガス化炉として利用できる見込みである。
併せてガスタービンも開発しており、高効率ガス燃焼により熱効率は 50%が望める。
米国の DOE 実施の FutureGen では IGCC 用シンガスまたは水素タービンの開発により2010 年までに 2～3%の向上、設備投資額 1,000 ドル/kW 以下に向け水素タービンの燃焼や材料開発を進めているところである。
米国カーソンでの IGCC プロジェクトは石炭及び石油コークスをガス化し 500MW を出力し、CO2 を捕集し EOR として利用・固定する予定で計画が進行している。
中国においては、GE のガス化炉建設を過去 5 年間で 15 箇所ライセンス契約している。現在
中国にて稼働している 4 基のガス化炉はトラブル等の停止等、信頼性、有効性は 90%以上を保持している。その他、低熱量ガスのガスタービンは製鉄所や製油所にて順調に 5 基稼働し2 基が計画中である。
GE は唯一のガス化及びガスタービンの商用化の実績を持つメーカーであり、今後の IGCC
プロジェクトに貢献できる。

講演 8
CO2 Recovery from Power Plant using Oxy-fuel Combustion
System Feasibility Study & Combustion Test Results
酸素燃焼発電所からの CO2 回収 FS と燃焼試験結果
Mr. Keiichiro Hashimoto, Manager, Boiler & Environmental
Group, Research & Development Department, Power Plant
Division, IHI Corporation (Japan)㈱IHI 電力事業部開発部 主査 橋本敬一郎氏（日本）
化石燃料が世界中で使用され、増加していく中、CO2 の削減には、高効率化によるエネルギ
ー使用の抑制、再生エネルギーの使用、発電所からの CO2 回収の三つのアプローチがあると考えられ、本日は CO2 回収について述べる。
特に酸素燃焼パイロットプラント試験について詳しく述べる。
90 年代に基礎テストを開始し、NEDO の支援のもと、2004 年から 2 年間、日豪共同研究として豪州で実証プラント試験を行った。ここでは数値シミュレーションと酸素燃焼試験の二つのアプローチを実施した。
日豪プロジェクトについて説明する。
QLD 州の既存発電所の近郊という条件で CS Energy 社カライド A 発電所を、また、CO2 貯
留サイトは発電所から 250m 離れた場所を選定した。
2008 年に建設を開始し 2010 年に操業を開始する予定。2011 年にフルスケールの CO2 圧入を開始する予定。2014 年にデモンストレーションプロジェクトが終了する予定。

日本における既存の 1,000MWe 微粉炭焚きボイラの酸素燃焼研究では、CO2 回収率 95%、
年間 5 百万トンの CO2 回収量、回収費用としてトン当たり 3,000 円と予測している。
Q&A
Q1： CO2 回収コストのグラフだが、単位は US$か。また、どのようにコストを計算したのか。
A1： 単位は日本円である。
Q2： IGCC についてコスト計算をしたことはあるか。
A2： IGCC は他のシステムに比べるとかなりコストは高い。CO2 回収の場合、IGCC は水素燃焼タ
ービンが必要でまだ商業運転されていないと思う。燃焼後 CO2 回収システムはオキシダント
による環境問題があるし開発コストも高い。これに比較して酸素燃焼 CO2 回収システムは装置（ボイラー、排ガス浄化装置）が小さくすることができる。したがって、現地点では我々が開発中の酸素燃焼方式が優れていると思う。

講演 9
CFE Technology with Chinese Own Intellectual Property
国産 CFB ボイラ技術
Mr. Sun Xianbin, Chief Scientist, Chief Engineer, CFB Boiler
Technology Department, Thermal Power Research Institute(TPRI) (PR China)
中国熱工研究院 CFB ボイラ技術部 主任科学者 主任技師
スン・シアンビン氏（中国）中国における CFB ボイラの技術開発は、1996 年に初めて 100MW CFB ボイラが導入され、現在は外国製の 300MW CFB ボイラ 9 基が稼動している。2008 年には国産の 330MW
CFB ボイラが稼動する予定である。
TPRI はこの国産大型 CFB ボイラの建設のために、重要な技術核心部である熱交換器や炉高などのシミュレーションを実施してきた。また、大型化のために熱交換器と炉のレイアウトについても検討してきた。
そして 2003 年 6 月にハルビンボイラ会社と共同で H 型配置の 100MW CFB ボイラを Fenyi
発電所に導入し 4 年間運転している。また、このタイプは無煙炭にも適用できるため、ベトナムの Sondong 発電所に建設中である。SOx、NOx などの排出量に関しても良いパフォーマンスを発揮している。
2006 年７月に四川ボイラ会社と共同で大型化のため外部熱交換器を設備した 220MW CFB
ボイラを Fenyi 発電所に導入した。
そして現在は、ハルビンボイラ会社と共同で中国最大 330MW CFB ボイラが建設中で 2008
年 10 月に稼動予定である。
TPRI では更に大型の CFB ボイラの設置に向けて 600MW 超臨界圧 CFB ボイラの概念設

計を終了している。
ここ 10 年の CFB ボイラの開発によって、中国はクリーンな発電技術を得た。CFB ボイラは特にアジア諸国において適用が可能である。揮発分の少ない無煙炭や低品位炭でも燃焼が可
能である。

⑩

第 9 セッション Flue Gas Cleaning Technology 排煙処理技術

議長 1：Dr. Frank Mourits, Senior Science and Technology Advisor, Office of Energy
R&D, Natural Resources Canada (Canada)
カナダ天然資源総局 エネルギー研究所 上級科学技術アドバイザー
フランク・モーリツ博士（カナダ）

講演 1
Study of Application Issues of SCR on Chinese Coal Fired Utility
Boilers
中国の石炭火力発電所における選択接触還元脱硝技術適用問題
Mr. Wang Yueming, Head, National Engineering Research Centerfor Clean Coal Combustion (NERC) (PR China)
国立石炭燃焼技術センター センター長 ワン・ユミン氏（中国）NOx 排出低減のための選択接触還元脱硝技術(SCR)は近年建設を行われている大型発電所に急速に普及しつつあり、中国国内で運転中もしくは、建設または計画のものが約 100 基あり、6 割以上が 600MW 以上の設備に適用されている。当初は諸外国の SCR 技術が導入されていたが、国内で製造することが可能になった。
中国における火力発電所の使用炭質が諸外国と大きく異なるため、それぞれに応じて最適化する必要がある。
また、低 NOx バーナーの採用に伴ない、ボイラから排出される NOx 濃度が 200～300mg/Nm3と低いため、SCR が低効率で稼働しても現排出用件を満たすこととなり、今後基準値が高めら
れ、SCR の能力が問われるときに最適化の問題は大きくなる。
炭質と燃焼条件によっては SCR の触媒が不活性となり接触脱硝能力が失われることは導入した先進国の研究で分かっている。
また、高カルシウム分の灰がハニカム型触媒の表面に付着し能力低下を招いていることなども分かっている。排煙中のフライアッシュ濃度は触媒を侵食し損傷させることもある。中国のボイ
ラは褐炭、瀝青炭、無煙炭等燃焼のカバー範囲が広く、522 のサンプルを分析してみると含有灰分量は 10～30%のものが多く、かなりの炭種が 30%を超えること、また硫黄分についてはその殆どが 2%以下であることが分かっている。国内 26 の発電所を調査した結果、灰の鉱物組成

は二酸化珪素と三酸化アルミニウムが 60～80%のものが多く、灰の高度が相対的に高く磨耗性が大きいことも特徴である。代表的な炭種である高カルシウム粘性のフライアッシュの場合、
SCR 導入にあたっては、触媒表面が汚れないように、シミュレーションと物理モデル試験を通じて、排煙の流れを最適化をしたりスートブローの適正化を行い、ピッチが大きい触媒の採用等が必要である。触媒側の耐侵食磨耗性を向上した材料の導入も必要となってくるなど、中国の発電所のボイラに SCR 技術を導入するにあたって主要パラメーターを目的に合わせて選択することが重要である。
Q&A
Q： 中国における SCR の今後の導入の予定はあるか。
A： 今後、窒素酸化物の規制が引き上げられると SCR 導入が加速するものと思われる。大きなシェアーが存在する。コストの問題はあるものの導入する技術の確立が肝要である。

講演 2
New Technologies for Emissions Reduction and Steam Plant
Efficiency Improvements
蒸気プラントの排出削減と効率向上
Mr. Tom Dendy, Director, Global Market &Application Development, SPX Thermal Equipment &Services (US)SPX 発電設備サービス社 世界市場開発部 部長 トム・デンディ氏（米国）
冷却システムの効率の改善により、ボイラで使用する燃料を節減することは排出削減を意味している。また、電気集塵システムの改善により煤塵排出が削減可能である SPX の技術を紹介する。
プラントの熱効率はボイラ出口温度とボイラ戻りの冷却後の温度の差を冷却後の温度で除したものが最大効率となる。また、プラントの効率は発電機にて出力した値と燃料消費量の比である。冷水の温度が 10℃高くなると 4%程度燃料消費量が増加し、プラント効率は低下する。冷却関係で効率を低下させる項目として、クーリングタワーの空気量の減少、クーリング水量の低下、雰囲気湿度の上昇があり、これら項目を防止させることが冷却水温度低下、つまりプラントの効率改善に繋がるため 2005 年に開発した 25.4mm のシート間隙を持つ低充填材使用汚水処理
装置は有効である。これを適用すると燃料消費量が 1%、夏場にあっては 2.5%節減できる。
その他の冷却に係るケーススタディーでは強制通風冷却塔では側入風式から逆流方式に変えることや、冷却充填材の材料変更や冷却塔の適性化・再設計などがある。
煤塵捕集技術においては、排煙中のダスト粒径分布の均一化と流速の最適化が課題となる。
フロー中の微粒子の帯電を高電流、捕集するダストを高電圧低電流とする帯電と捕集する部

分を分割した Bi-Corona 法とすると、フローがアンバランスな従前の電気集塵機と比較して 30%の捕集率向上が期待できる。また、Bi-Corona の給電装置には高周波スイッチモードの給電装置を使用するとエネルギーロスを 20%防止することも出来る。
Q&A
Q： 乾式冷却方式を採用している発電所では特に夏場の冷却不足による発電所の効率低下が危惧されている。このようなハードなコンディションでも対応が可能か。
A： スペック過剰はかえって効率低下を招く。年間の気温の変化、ボイラの負荷状況等、それぞれ発電所の条件により最適化する必要がある。

講演 3
High-Efficiency SO2 Removal Using Activated Carbon Fibers
活性炭素繊維を用いた高効率 SO2 除去技術
Dr. Miftahul Huda, Senior Researcher,
Coal & Mineral Technology R&D Centre, Agency of R&D for
Energy and Mineral Resources, Ministry of Energy and Mineral
Resources (Indonesia)
エネルギー・鉱物資源省 エネルギー鉱物資源研究所 主幹研究員 ミファタフル・フダ博士（インドネシア）
現行の湿式の排煙脱硫システムは、高額な設備投資が伴い、運用面で大量の水を消費するとともに低価格の CaSO4 の副生成物が発生すること、また 30ppm 以上が域外にリークすること
より、より高度な排煙脱硫法について活性炭素繊維(ACF)に着目してその効果を調査した。
ACF の脱硫メカニズムは表面や微細組織構造により、SO2 が酸化し、SO3 となり水が加えられることにより、H2SO4 として捕捉されることが考えられている。
ACF の課題は SO2 を除去へ ACF を活性化させることによりコスト低減を図ることである。低酸
素濃度ガスによる ACF 酸化方法で表面の化学性状を改善することである。研究に用いた大阪ガス社の OG15A の表面積 1,450m2/g である。酸化処理は 1,100℃のアルゴン雰囲気中で行ったものを用い、2%低酸素加熱処理を 0.5 時間～2 時間処理したものを使用し、1,000ppmのガスを使い固定床ダウンフロー反応器で脱硫特性の実験を試みた結果、60%～90%の脱硫率が確認されている。
また、SO2 濃度別や酸化時間別にも確認を行った。結果 ACF による脱硫システムは酸化処理を行うことにより効果的になること、酸化処理は表面と活性化部を向上させることが把握できている。
Q&A
Q： インドネシアの石炭火力発電所で実際に本活性炭素繊維を用いた排煙脱硫装置の稼働状
況はどうか。

A： まだ実験室レベルの研究である。しかしながら活性炭素繊維の特性は概ね分かっているので、実用化に向けて今後研究を進めて行きたい。

講演 4
SCR Key Technical Choice for Coal-fired Power Plants Removal
Nitrogen Oxides
石炭火力発電所における SCR の技術選択
Dr. Zhang Qiang, Head, SCR Group, Thermal Power ResearchInstitute (TPRI) (PR China)
西安熱工研究院 SCR グループ グループ長 ゾン・キン博士（中国）中国での窒素酸化物の排出基準は 2003 年に発効された BD1323 であり、これによると450mg/Nm3 となっている。
最近の国家環境保護部門の情報によると、出来るだけ早く窒素酸化物の排出抑制を行う
計画があり、地域別によりその環境基準は異なると考えられている。従って、これに対応するためには排煙脱硝装置が必要となり、我々は選択接触還元脱硝技術(SCR)の設置を提案する。現在のところでは低 NOx 燃焼技術の導入により、ボイラから排出される NOx はある
程度従前と比較して低減されているので、ボイラの診断がまず必要である。
SCR の設置にあたり、触媒は、液体アンモニア、アンモニア水、及び尿素の 3 種類があり、一長一短の特徴を持っており、大型の発電所でアンモニアの使用量が多い場合には、コスト削減の観点より液体アンモニアを選択し、安全面を考慮する場合、尿素を選択することを推奨する。小型の発電所の場合は液体アンモニアを使用することも考えられる。
具体的に SCR の触媒を選択する場合、石炭中の窒素分、硫黄分、その他の微量元素の含有量や石炭灰中の酸化カルシュウム、酸化砒素、灰の粘性、粒度分布のパラメーターを考慮する必要がある。
SCR の設置位置については、ボイラー後段のエアヒーター前に設置する高ダスト法が望ましいが、既存設備の改造の場合等で設置スペースの問題等がある場合、低ダスト法を選択することも可能である。
SCR の持続的効率の維持のためスートブローを行うが、蒸気スートブローが確実の方法であるが、設備投資の少ないソニックブロー法も開発されている。
SCR の設計の重要なポイントは還元剤と排煙中の窒素酸化物の流動混合を最適化させることであり、SCR 反応器の煙道の長さ、システムの圧損、混合距離、投資金額等を考慮し、適切なアンモニアの噴射方式を選択することが重要である。

講演 5
Why select Air Monitor technology for total airflow measure?
Air Monitor 社の通風計測技術をなぜ選択するか？
Mr. David Dunn, Asia-Pacific Sales Manager,
Air Monitor Corporation (US)
エアモニター社 アジア太平洋販売部長 ディビット・ダム氏（米国）
火力発電所における通風モニタリング、管理により、燃焼の安定性向
上や未燃炭素分減少、通風不足によるボイラの爆発事故の防止、火炉壁の磨耗、スラグ付着や腐食の防止、ボイラ熱効率の向上に大きく寄与する項目の一つである。
また流動床ボイラでは流動層の高さのキープや滞流を防止する重要な項目であり、層内温度管理にも影響する因子である。ボイラ内の通風制御は直缶部分が少ないことや形状の変化による通風速度の違い等により正しい通風計測は非常に難しく、設計においても無視される場合がある。複雑な缶内の通風状態を管理する上では多数の計測ポイントが必要となり、計測点の位置も重要となってくる。
Air Monitor 社ではボイラ・煙道等中の正しい流動状態が把握できるように技術標準を作成した。また、計測器やその解析に係る技術開発も行っている。
Air Monitor 社のモニタリング機器を使用することにより、計測制度が向上し、過剰空気を低減させ、燃焼条件を適正化することによりボイラ効率を高めることが出来る。従来計測機器と比較
して 5%以上の省エネが期待できる。併せて、燃焼状態の正確な把握によりサーマル NOx を低減させる効果も期待できる。

⑪ 第 10 セッション Power Plant Automation and Information Technologies
発電所の自動化・情報化技術
議長 1：Mr. Liu Wei, Vice President, Thermal Power Research Institute (TPRI)
西安熱工研究院 副院長 リュー・ウェイ氏（中国）

講演 1Supervisory Information System at Power Plant Level (SIS) andIts Development
プラントレベルにおける情報管理システムとその開発
Mr. Yang Dong, Deputy Director, Power Plant,
Maintenance Optimization and Software Department,
Thermal Power Research Institute (TPRI) (PR China)

西安熱工研究院 ソフトウエア管理部門 発電課 次長 ヤン・ドン氏（中国）SIS(Supervisory Information System at Plant Level)は管理レベル(DCS)、実行レベル(MES)、計画レベル(ERP)に係る各レベル調整を行う管理システムのソフトである。
1990 年代後半に発電所と製造工程における情報管理システムが先進国から導入され、ほぼ同時期に中国で開発中のプラントレベルの情報管理システムを統合化したものである。
SIS は、プラント生産プロセスの自動化システムであり、プラント稼働における履歴とリアルタイ
ムの生産プロセスを統合し、プラントの生産管理とプロセス全体の管理の橋渡しを行い、全体のプラント生産プロセスの最適化に資するものである。
本システムの開発については 1997 年中国にてコンセプトが誕生し、翌年電力省にて認可、
2002 年化石燃料を用いる発電所の設計に応用され、研究開発が TPRI に委託された。
TPRI の SIS プロジェクトは、2007 年には国家科学技術賞を受賞した。
本システムの導入によりユニット単位、プラント単位での最適化によるエネルギーロス改善や省エネルギーについての経済評価が可能となる。石炭消費量では最低 0.5～1.5g/kWh の節減となる。
300MW 級ボイラ 4 台の火力発電所ではボイラ給水用ポンプ等の制御により、石炭消費量にして 1.0 g/kWh の節減が可能となる。その他蒸気タービンの最適化により 2.63 g/kWh を節減することも可能である。
本システムは 300～600MW 級亜臨界圧ボイラ、600MW 級超臨界圧ボイラ、600～
1000MW 級超々臨界圧ボイラ、循環流動床ボイラ等に適用できるようになった。その他、主要機器、補器の監視、爆発や高温による破裂事故の未然防止、各機器の補修時期の判断と併せて瞬時の最適な運転操業管理が可能となる。
今後本システムの導入により、プラント操業に係る瞬時の状況診断、管理制御が可能となる適正化された火力発電所が拡大することを望む。

講演 2
Development of New Technology and Informationalization inPower Plant Equipment Management
発電所における新技術開発と機器管理の情報化
Mr. Zhong Jindong, Deputy Director General,
Weihai Power Plant (PR China)
華能威海発電所 副部長 ザオ・ジンドン氏（中国）
発電所機器のメンテナンスコストは発電所にとって大きな負担となっている。先進的なメンテナ
ンス技術を開発すればコストの低減及び機器の信頼性を高めることになる。この技術がCMMS（Computer Maintenance Management System）である。
CMMS は諸外国で多くの企業が採用しているが、低成功率、機能不足などの欠点がある。

現在、中国の発電所メンテナンスは定期点検で行っている。機器の故障予防としては良い役
割を果たしているが、不必要な整備も行うことになる。昨今では機器の状態によってメンテナンスを行う CBM（Condition-based Maintenance）が多くの発電所で採用されている。CBM
は機器の状態に従ってメンテナンスの時期を決める。そのため、機器故障の目安を決めるた
めに故障履歴、メンテナンス履歴、ライフサイクルなどを評価しなければならない。
資産のライフサイクル管理は CMMS による企業資産管理 EAM(Enterprise AssetManagement)によって行われてきている。

講演 3
HPI Fuel Centralized Payment Management System
華能国際電力における燃料支払い管理システム
Mr. Zhao Anxiang, Huaneng Power International Inc (PR China)
華能国際電力公司 ザオ・アンシェン氏（中国）
華能国際電力は中国最大の電力会社で発電設備容量は 2007 年 1
月で 28GW に達している。中国全土に 17 発電所をもち、この内株式の過半数をもつ発電所は 13 箇所、少数の株をもつ発電所は 4 箇所である。華能国際電力
公司は、中国初の国産 600MW 超臨界圧ユニットを大連に建設し、現在、中国最大規模となる玉環(Huaneng Yuhuan)発電所を建設中である。
中国 5 大電力間の競争と石炭価格の上昇のため利益が圧迫され、2004 年には電力生産の60%以上が燃料費であった。このため、燃料管理として調達、運搬、決済の 3 つの集約化戦略を立てた。決済の集約化を行えば、調達の透明性が高まり、徐々に供給と契約も集約されていく。以前、各発電所はそれぞれ違うシステムを採用していた。
燃料費の削減のために 2004 年から 1 年間、中央支払いシステムを導入した。以前は FAX と電話を使ったものでデータ集積は困難であったが、2005 年に IT 企業である Microsoft 社と契約し、現在では効率良い管理システムとして運用している。

講演 4Foundation of Digital Power Plant is Fieldbus Control Sytem
デジタル発電所の基礎～フィールドバス・コントロール・システム(FCS)
Mr. Yan Yuping, Scientist, Chief Engineer,
Department of Fieldbus and Control Technology,
Thermal Power Research Institute (TPRI) (PR China)
西安熱工研究院 フィールドバスコントロール技術部
主幹技師 ヤン・ユピン氏（中国）発電所の効率化、環境保護の観点から、フィールドバスコントロールシステム（FCS）による「発電所のデジタル化」が研究されている。TPRI では発電所に FCS 技術を適用するための研究に取り組んでいる。
最初の FCS が華能玉環発電所(Huaneng Yuhuan Power Plant)に導入された。TPRI は、
プロフィバス、HMI、PLC などのネットワークやフィールドバス機器、ソフトウェアを組み合わせた発電所の水管理 FCS を導入し 2006 年 2 月より操業している。その中のソフトウェア（管理診断ソフト）では中国語のインターフェースを用いている。水管理に関して従来の PLC と経済性を比較解析したところ FCS は勝っていた。
次の段階として発電機制御における FCS の設計に取り組んでいる。
発電所のデジタル化は今後の主流になって行く。そして華能集団の技術センターとしてTPRI はこの分野の革新に取り組んでいく。

⑫ 閉会セッション Closing Session
Seminar Summary セミナーサマリー：
Mr. Jiang Minhua, Director TPC/CSEE and President , Thermal
Power Research Institute (TPRI) (PR China)
中国電力エンジニア学会 火力発電部会 事務局長
西安熱工研究院 院長 ジャン・ミンハ氏（中国）
2 日半にわたるセミナーの期間中、各専門家の優れた発表と参加者による熱心な討議を中心に、友好的かつ中身の濃い交流が行われ、先ほど、全てのプログラムを無事に終えることができた。
今回のセミナーでは、アジア太平洋地域の石炭の生産と需給の将来展望、及び環境調和的で持続可能な石炭火力発電のためのクリーン・コール・テクノロジーを中心とする石炭関連技術について幅広い情報交換が行われた。
参加者については、中国各地および海外各国から、石炭関係者及び電力関係者を中心に、多数の人が幅広く集まり、年齢層も広範囲で中国側の最年長者は 80 歳だった。
セミナーを通じ、各参加者がそれぞれの関連分野でよりクリーンで効率の高い石炭の利用を目指し真剣に取り組んでいることがわかったが、我々が直面しているエネルギーと環境の問題
は世界共通の大きな問題であり、解決のためには世界全体の関係者の協力が必要不可欠である。今回のセミナーの最大の成果は、今後の協力に向けて、関係者の間に「橋をかける」ことができたことであると思う。
最後に、セミナーが成功裏に閉幕できたことについて、開催のために努力された各国関係者の皆様に改めてお礼申し上げる。

閉会の辞
Mr. Scott Smouse, EGCFE Chair,International Coordination Team Leader, National Energy
Technology Laboratory (NETL), Department of Energy (DOE)(US)
APEC EGCFE 議長 スコット・スマウス氏（米国）
エネルギー省 国立エネルギー技術研究所 国際協力チーム長
今回のセミナーでは、石炭が現在 APEC 地域だけでなく世界中で直面している需給や環境等の問題について、政策や技術の面から幅広く意見交換を行うことができ、非常に有意義であった。
APEC 地域には、引続き石炭によるエネルギーが供給され続けるだろうが、今後、需要に合わせて大規模な発電所が次々に新設されると、現在の技術では、環境面の問題に対応できなくなるだろうということが明らかになりつつある。
世銀によれば、現在世界でまだ 20 億人の人々が電気の恩恵に浴していないが、彼らに電気を供給しようと思うならば、石炭を含めあらゆるエネルギー源を検討対象とすべきである。エネ
ルギーには「悪い」ものなどはなく、悪いとされるのはその「使い方」であろう。
エネルギー・セキュリティーと気候変動の問題は、今世界中で、政府や企業、NGO 等により熱く議論されている政治的社会的問題で、ご存知のように石炭は批判にさらされている。しかし、この問題について下される決定は、影響が非常に大きいので、政府と企業が健全な判断を行うためには一般市民を含めたオープンな議論が必要である。市民の側は、石炭をなぜ、どのように使うのかの議論は、専門家と政策決定者との対話のみでは不十分であるとして、NGOや裁判、マスコミ、インターネット等あらゆる手段を通じ対話に加わろうとしている。
石炭への批判を封じるには①ゼロエミッションを目指したクリーン・コール・テクノロジーを開発すること

②この技術を、必要に応じ競争力のある価格で市場に供給できるようにすること

③電力や輸送燃料等を最終消費者に適正な価格で供給できる市場を整備すること

④各国の政府や市民に、新しいクリーン・コール・テクノロジーを適用すれば、石炭は、
家庭、学校、病院、事務所、工場等への信頼できる電力供給源であり続けると伝えることが必要である。
脱炭素社会を目指す研究開発が進められてはいるが、APEC 地域の経済は今後数十年は化石燃料に依存せざるをえない。APEC 地域では他の地域と同様、環境に悪影響を与えずにエネルギー需要を満たすという課題に直面している。
EGCFE は、石炭が極力クリーン且つ効率的に利用されるよう、幾つかの具体的なプロジェク
トを推進中であるが、今回のセミナー参加者を始め、今後とも関係者との交流を継続していきたい。
今回のセミナー開催のために努力して頂いた各国政府関係者や裏方の皆さん、また、長年
APEC セミナーに貢献して頂いた JCOAL 安藤理事長にお礼を申し上げたい。

3.

需給予測結果取纏め

APEC 各国から収集した石炭需給に関するデータを整理し、APEC 化石燃料専門家会合（APEC
EGCFE/ Expert Group on Clean Fossil Energy）Business Meeting（APEC EGCFE の各国政府代表者による特別会議）で収集したデータ結果に基づく需給予測結果の報告を行った。
次頁にその報告に使用した資料を掲載する。

１．World Coal Consumption
Coal Consumption by Coal Type

Coal Consumption by Region（Million tonnes）
10,000

Actual（Million tonnes）

Forecast

Increase of Consumption(2004－2030)

9,000

（Mt）

3,196

9%

4,100Mt

8,000

7%

7,000

570

193

17%

139

6,000
Asia

N. A.

EuropeLatin America,
Middle East
Oceania

9,000

Africa7,000

OECD Europe

Others

5,000

FSU, Non OECD
EuropeN.America

15%

4,000

9%

3,000

27%

19%

2,000

23%

1,000

ActualForecast

10,000

62%

50%

1990

2000

348

147

Coking

Steam

Brown
Steam Coal

5,000

16%

79%

4,000
23%
Coking Coal

62%

1,000

2004

Actual

2010

2020

15%
0
1980

2030

(Million tonnes)
Average Annual Growth Rate（%）

Forecast

1980

2004

2010

2020

2030

Asia

896.5

2,795.0

3,848.1

4,975.6

5,991.4

4.9

5.5

2.6

1.9

3.0

N. America

674.8

1,063.3

1,146.1

1,300.8

1,633.6

1.9

1.3

1.3

2.3

1.7

FSU, Non OECD Europe

827.8

498.5

597.5

664.9

685.2

-2.1

3.1

1.1

0.3

1.2

OECD Europe

993.4

815.0

820.3

836.2

821.4

-0.8

0.1

0.2

-0.2

0.0

Africa

98.0

195.0

188.2

217.9

246.0

2.9

-0.6

1.5

1.2

0.9

OECD Oceania

69.2

137.3

141.4

158.8

175.2

2.9

0.5

1.2

1.0

0.9

Latin America, Middle East

21.2

61.1

73.6

91.9

111.3

4.5

3.2

2.2

1.9

2.3

3,580.9

5,565.1

6,815.2

8,246.3

9,664.1

1.9

3.4

1.9

1.6

2.1

Total

Brown Coal

3,603

73%

25%
0
1980

11%

6,000

2,000

19%

（Mt）

4,100Mt

8,000

3,000

Asia

Increase of Consumption(2004－2030)

1990

2000

2004

Actual04/80 10/04 20/10 30/20 30/04

10%

11%
2010

2020

2030

(Million tonnes)
Average Annual Growth Rate（%）

Forecast

1980

2004

2010

2020

2030

Coking Coal

529.4

586.6

774.3

901.4

935.0

04/80 10/04 20/10 30/20 30/04
0.4

4.7

1.5

0.4

1.8

Steam Coal

2,222.2

4,070.1

5,073.3

6,311.7

7,673.2

2.6

3.7

2.2

2.0

2.5

Brown Coal

829.3

908.5

967.7

1,033.1

1,055.9

0.4

1.1

0.7

0.2

0.6

Total

3,580.9

5,565.1

6,815.2

8,246.3

9,664.1

1.9

3.4

1.9

1.6

2.1

２．Coal Consumption in Asia
Coal Consumption by Country (Region)

Coal Consumption by Country (Region)

Chinese Taipei

3%
2,000

63%

1,000
12%

39

460Mt

60

Malaysia
Philippines
Viet Nam
Indonesia
Chinese Taipei
Korea

200

Japan
1990

2000

2004

2010

2020

100

2030

0
1980

Actual(Million tonnes)
Average Annual Growth Rate（%）

Forecast

1980

2004

2010

2020

2030

China

603.7

1,895.0

2,711.8

3,343.2

3,760.4

4.9

6.2

2.1

1.2

2.7

India

113.7

438.7

592.3

908.4

1,310.7

5.8

5.1

4.4

3.7

4.3

Japan

87.6

172.9

176.4

183.0

181.6

2.9

0.3

0.4

-0.1

0.2

Korea

27.8

80.3

99.4

119.6

131.9

4.5

3.6

1.9

1.0

1.9

Chinese Taipei

5.9

57.1

62.0

91.8

126.8

9.9

1.4

4.0

3.3

3.1

Indonesia

0.2

36.2

59.8

98.9

147.1

23.6

8.7

5.2

4.1

5.5

Viet Nam

4.1

14.9

23.0

49.6

77.6

5.6

7.5

8.0

4.6

6.6

Philippines

3.1

14.3

16.5

19.9

31.8

6.5

2.4

1.9

4.8

3.1

Malaysia

0.1

10.7

17.5

30.7

49.7

22.9

8.6

5.8

4.9

6.1

Thailand

1.5

25.8

32.2

44.2

64.9

12.5

3.7

3.2

3.9

3.6

Others

48.7

49.1

57.2

86.3

108.9

0.0

2.6

4.2

2.3

3.1

896.5

2,795.0

3,848.1

4,975.6

5,991.4

4.9

5.5

2.6

1.9

3.0

Total

17

39

300

68%
0
1980

Thailand
63

400

India
China

68%

70

9

500

Japan

16%

52

700
600

Korea

Others（Mt）

OthersIndonesia

Forecast

111

800

Malaysia

21%

Others111
Indonesia

Korea

Japan

India

China

3,000

70
ChineseTaipei

52

9

4,000

218

Increase of Consumption(2004－2030)

900

OthersViet Nam

3,200Mt

872

ActualPhilippines

5,000（Million tonnes）
1,000

Indonesia（Mt）

Thailand

6%
2%
2%
2%
3%

Korea

Increase of Consumption(2004－2030)

1,865（excluding China and India）

Forecast

ChineseTaipeiActualJapan（Million tonnes）
6,000

04/80 10/04 20/10 30/20 30/04

1990

2000

2004

2010

2020

2030

Coal Consumption by Sector

Coal Consumption by Coal Type（Million tonnes）
6,000

Actual（Million Tonnes）
6,000

Forecast2%

Increase of Consumption(2004－2030)

（Mt）

2,809

3,200Mt

Steam

Brown

87%

3,000

4%

Increase of Consumption(2004－2030)

（Mt）

14%

Steam Coal

2%

Others3,200Mt
4,000

69
Coking

Forecast

Brown Coal

319

4,000

3,000

Electricity,
Heat

391

322

Coke
Ovens

Industry13%

Industry-55
Others10%

2,000Coke Ovens

18%

2,000

70%

13%

Coking Coal

85%
1,000

2,539

5,000

5,000

ActualElectricity,Heat

2%

1,000
80%

18%
0
1980

13%
1990

2000

2004

Actual
1980
Coking Coal

11%

162.1

2010

2020

350.0

2010
523.2

2020
633.8

17%
22%
0
1980

2030

(Million tonnes)
Average Annual Growth Rate（%）

Forecast

2004

25%
34%

2030
668.9

6.9

1.9

0.5

1990

2000

2004

Actual04/80 10/04 20/10 30/20 30/04
3.3

58%

2.5

Electricity

Steam Coal

713.6

2,382.5

3,249.9

4,232.6

5,191.0

5.2

5.3

2.7

2.1

3.0

Heat

Brown Coal

20.8

62.5

74.9

109.2

131.5

4.7

3.1

3.8

1.9

2.9

Coke Ovens

Total

896.5

2,795.0

3,848.1

4,975.6

5,991.4

4.9

5.5

2.6

1.9

3.0

2010

2020

2030

(Million tonnes)
Average Annual Growth Rate（%）

Forecast

1980

2004

2010

2020

2030

196.3

1,516.9

2,243.2

3,113.1

3,978.504/80 10/04 20/10 30/20 30/04
8.9

6.7

3.3

2.5

－

115.5

149.6

177.5

193.2

－

4.4

1.7

0.8

2.0

156.0

363.8

591.9

718.3

754.4

3.6

8.5

2.0

0.5

2.8

3.8

35.1

123.3

120.5

123.8

127.1

5.4

-0.4

0.3

0.3

0.1

Transformation

387.4

2,119.4

3,105.3

4,132.7

5,053.2

7.3

6.6

2.9

2.0

3.4

Industry

306.5

500.8

589.0

711.6

822.5

2.1

2.7

1.9

1.5

1.9

OthersFinal Consumption

202.5

174.8

153.9

131.3

115.7

-0.6

-2.1

-1.6

-1.3

-1.6

509.1

675.5

742.8

842.9

938.2

1.2

1.6

1.3

1.1

1.3

Total

896.5

2,795.0

3,848.1

4,975.6

5,991.4

4.9

5.5

2.6

1.9

3.0

Own Use, etc.

３．Coal Production in Asia
Coal Production by Coal Type

Coal Production by Country (Region)（Million tonnes）
6,000

1,778

5,000

ActualIncrease of Consumption(2004－2030)

Increase of Consumption(2004－2030)

（Mt）
7%

Forecast

42

3Viet Nam

Thailand

22%

28

（Mt）

2%

5,000

251

4,000

Indonesia

CokingBrown Coal

2,990Mt

Thailand
Viet Nam

Others268

Others2,568

2,990Mt
Indonesia

India

4,000
China

Actual

6,000

769

3,000

（Million tonnes）

Forecast

69
Steam

Brown
Steam Coal

3,000

88%

2%

5%
India

16%

2,000

2,000

68%
1,000

1,000
74%
1990

2000

ActualChina
India
Indonesia
Viet Nam
Thailand
Others
Total

2%

75%

14%
0
1980

Coking Coal

88%

China

1980
620.2
116.1
0.3
5.2
1.5
89.8
833.0

2004
1,960.3
413.0
132.4
25.5
20.1
49.3
2,600.5

2010
2,696.8
538.9
240.0
37.8
23.5
55.5
3,592.4

2004

2010

2020

2030

Forecast(Million tonnes)
Average Annual Growth Rate（%）

2020
3,320.7
816.9
320.0
52.8
25.1
65.3
4,600.82030
04/80 10/04 20/10 30/20 30/04
3,737.9
4.9
5.5
2.1
1.2
2.5
1,182.1
5.4
4.5
4.2
3.8
4.1
400.0 28.8 10.4
2.9
2.3
4.3
67.8
6.8
6.8
3.4
2.5
3.8
23.4 11.3
2.7
0.7
-0.7
0.6
77.3
-2.5
2.0
1.7
1.7
1.7
5,488.5
4.9
5.5
2.5
1.8
2.9

86%
12%
0
1980

1990

2000

2004

ActualCoking Coal
Steam Coal
Brown Coal
Total

9%

10%

1980
97.1
715.3
20.6
833.0

2004
252.3
2,285.462.8
2,600.5

2010
400.1
3,116.6
75.6
3,592.4

2010

2020

2030

Forecast(Million tonnes)
Average Annual Growth Rate（%）

2020
484.0
4,006.9109.9
4,600.82030
04/80 10/04 20/10 30/20 30/04
502.8
4.1
8.0
1.9
0.4
2.7
4,853.5
5.0
5.3
2.5
1.9
2.9
132.2
4.7
3.1
3.8
1.9
2.9
5,488.5
4.9
5.5
2.5
1.8
2.9

５．Coal Import in Asia

４．Coal Supply and Demand in Asia

Coal Import by Country (Region)

Comparison of Coal Consumption and Production（Million tonnes）
1,000.0

Forecast

Production

Increase of Consumption(2004－2030)
136
104
66
52
34 36

900.0

Consumption

6,000

800.0
700.0

5,000

ActualThailandIndia

Malaysia

China

Korea

500.0

ChineseTaipei

4,000

Japan

600.0

（Mt）

OthersPhilippines

470Mt
26

14

1

Forecast

Thailand
OthersActualPhilippines(Million tonnes)

7,000

Malaysia
India

400.0

3,000

China

300.0

2,000

Chinese Taipei

200.0

Korea

100.0

Japan

1,000
0.0
1980

0
1980

1990

2000

2010

2020

1990

2000

(Million tonnes)
Average Annual Growth Rate（%）

Forecast

2010

2020

2030

2030

ActualActual2004(Million tonnes)
Average Annual Growth Rate（%）

Forecast

1980

2004

2010

2020

2030

Japan

68.6

180.8

175.9

182.8

181.6

04/80 10/04 20/10 30/20 30/04
4.1

-0.5

0.4

-0.1

0.0

1980

2004

2010

2020

2030

Korea

5.0

79.0

97.0

118.2

131.1

12.2

3.5

2.0

1.0

2.0

Production

833.0

2,600.5

3,592.4

4,600.8

5,488.5

4.9

5.5

2.5

1.8

2.9

Chinese Taipei

4.6

60.6

62.0

91.8

126.8

11.3

0.4

4.0

3.3

2.9

Consumption

896.5

2,795.0

3,848.1

4,975.6

5,991.4

4.9

5.5

2.6

1.9

3.0

China

2.0

18.6

80.0

130.0

155.0

9.8

27.5

5.0

1.8

8.5

Gap

63.4

194.4

255.7

374.8

502.9

4.8

4.7

3.9

3.0

3.7

India

0.6

26.2

54.9

92.9

129.9

17.5

13.1

5.4

3.4

6.4

Malaysia

0.1

10.7

16.2

27.6

44.8

22.9

7.2

5.4

5.0

5.7

Thailand

0.1

5.3

8.7

19.1

41.5

18.2

8.6

8.2

8.1

8.3

Philippines

0.0

7.0

7.6

9.8

21.1

-

1.5

2.6

7.9

4.4

Others

1.5

15.4

17.6

27.7

41.5

10.4

2.2

4.6

4.1

3.9

82.4

403.6

519.9

699.9

873.4

6.8

4.3

3.0

2.2

3.0

(Note) Gap=Consumption - Production

04/80 10/04 20/10 30/20 30/04

Total

-2
0
2.2

Hong Kong

ThailandPhilippines

6.0

5.1

4.9

4.1

3.7

2.6

6.5

6.7

9.8

Annual Growth Rate : 2004 - 2030

5.7

6.2

5.4

5.2

5.9

5.7

6.1

6.4

Annual Growth Rate : 1980 - 2004

Viet Nam

Malaysia

Indonesia

India

3.5

GDP Growth Rate in the World

China

2

Chinese Taipei

4
6.9

6

3.5

6.9

8

Korea

2.4

5.4

（％）

1.5

3.8

3.9

4.9

10

Japan

1.7

3.7

2.4

2.9

2.2

2.7

4.9

4.7

4

Asia (excluding
Japan)

Asia

Middle East

AfricaLatin America

Oceania

-0.9
FSU
3.2

2.1

Non-OECD 0.9
EuropeOECD Europe

2.8

3.1

3.0

2.8

2

N. America

World

Reference
GDP Growth Rate in Asia

10

（％）

Annual Growth Rate : 1980 - 20048
Annual Growth Rate : 2004 - 2030

60

アジア／世界の石炭需給展望－アジアを中心とする 2030 年までの見通し
１．世界の石炭消費
世界の石炭消費は、アジアを中心に 2004 年から 2030 年まで年率 2.1%で増加し、2004 年の55.7 億トンから 2030 年には 96.6 億トンと 1.7 倍の規模にまで拡大する。石炭消費量は OECD
欧州を除いて各地域で増加するが、主に発展途上国での増加が著しい。特に世界の石炭消費増加
量の 8 割近くがアジアによるもので、その増加を牽引する中国とインドの増加量はそれぞれ世界の増加量の 46%と 21%を占める。アジアの石炭消費が電力需要の拡大に伴い発電用石炭を中心に急速に増加していることから、アジアの石炭消費が世界の石炭消費に占めるシェアは、1980 年の25%から 2004 年には 50%まで拡大している。今後も発電用石炭需要を中心にアジアの石炭消費は増加し、世界の石炭消費に占めるシェアは 62%まで拡大し、石炭消費におけるアジアのプレゼ
ンスが高まることになる。
炭種別の消費量をみると、発電用石炭需要が増加することから一般炭の消費が著しく増加する。
一般炭の消費は、2004 年から 2030 年まで年率 2.5%で増加し、2030 年には 2004 年の 1.9 倍の76.7 億トンまで増加する。一方、原料炭の消費量は年率 1.8%で増加し、2030 年には 2004 年の1.6 倍の 9.4 億トンとなる。なお、褐炭の消費量は、発電用需要増により微増する。このように2030 年までの石炭消費増加量の 9 割弱が一般炭によるものとなる。
２．アジアの石炭消費
アジアの石炭消費は、経済発展に伴う電力需要の拡大により発電用石炭を中心に 2004 年から2030 年まで年率 3.0%で増加し、2004 年の 28.0 億トンから 2030 年には 60.0 億トンまで 2.1 倍に拡大する。
自国内に豊富な石炭資源を有する中国とインドでは、現在も大量の石炭を消費している。両国
では、今後も石炭を軸とした一次エネルギー構成が維持されることから、エネルギー消費の拡大に伴い石炭消費は増加する。2000 年代に入り急増している中国の石炭消費増加量は、次第に落ち着くと見られているが、2004 年から 2030 年まで年率 2.7%で増加し、2030 年には 2004 年の 2
倍の 37.6 億トンまで増加する。インドの石炭消費量は、発電用石炭を中心に 2030 年まで年率 4.3%
で順調に増加し、2030 年には 2004 年の 3 倍の 13.6 億トンに拡大する。2004 年から 2030 年までのアジアの石炭消費増加量の 58%が中国によるもで、27%がインドによるものとなる。
東南アジアでは、今後の電力需要の増加に伴い石炭火力発電所の建設が計画されており、石炭消費が拡大する。なかでも自国内に石炭資源を有するインドネシアとベトナムでの石炭消費の増加が著しい。インドネシアの石炭消費量は、2030 年まで年平均 5.5%で増加し、2030 年には 1 億
4,710 万トンと 2004 年の 4 倍にまで拡大する。ベトナムの石炭消費量は、年平均 6.6%で増加し、2030 年には 7,760 万トンと現在の 5.5 倍にまで拡大する。その他、石炭火力の建設が近年進められ天然ガス資源の温存から今後も石炭利用拡大を検討しているマレーシアや石炭火力建設が進められているタイにおいて石炭消費が増加する。一方、天然ガスの利用が多いと見込まれるフィリ
ピンでは石炭火力の建設計画は小規模に止まっており、石炭消費の増加は少ない。
東アジアでは、現政権が原子力発電廃止に向けた方針を打ち出している台湾で石炭消費は増加
する一方、原子力発電の推進を進めている韓国の石炭消費の増加はさほど大きくない。台湾では

現在建設中の原子力発電所が 2009 年に完成後、2010 年代後半から原子力発電所を順次停止する計画である。このため、2011 年以降の石炭消費の増加量は多く、2010 年の 6,200 万トンから 2030
年には約 2 倍の 1 億 2,680 万トンに達する。一方、韓国では原子力発電所の建設が計画されていることから石炭消費は 2030 年まで年平均 1.9％と比較的低い伸びを示し、2004 年の 8,000 万ト
ンから 2030 年に 1 億 3,190 万トンまで増加する。日本では、今後人口が減少するなか一次エネ
ルギー消費はほぼ横ばいで推移するが、老齢化社会において利用しやすい電力エネルギーは微増すると見込まれている。電源構成において原子力発電を 2030 年で 40%にするとしているが、新規建設には克服すべき多くの課題があることから、石炭消費量は横ばいないしは微増で推移し、2004 年の 1 億 7,300 万トンから 2030 年には 1 億 8,160 万トンとなると見込まれる。
炭種別でみると、一般炭の消費量は、発電用石炭需要が大きく拡大するほか、セメントを中心に一般産業での需要増も見込まれ、2004 年の 23.8 億トンから 2030 年には 51.9 億トンと 2004
年の 2.2 倍の規模に拡大する。一方、原料炭消費は、鉄鋼生産が拡大する中国、インドを中心に増加し、2004 年の 3.5 億トンから 2030 年には 6.7 億トンと 2004 年の 1.9 倍の規模に拡大する。
アジアの一般炭、原料炭の消費増加量は、それぞれ世界の消費増加量の約 8 割と 9 割を占めることになる。褐炭は電力向け需要拡大によりインド、タイで微増するほか、インドネシアでの利用が期待されている。
３．アジアの石炭生産
アジアの石炭生産量は、2004 年から 2030 年にかけて年率 2.9%で増加し、2004 年の 26.0 億ト
ンから 2030 年には 54.9 億トンまで 2 倍以上に拡大する。言うまでもなく、石炭消費が大きく増加する中国とインドでは、自国の需要を賄うために石炭生産が拡大する。その他、豪州に次ぐ輸出国であるインドネシアと無煙炭の輸出国であるベトナムでは、輸出需要に加え国内需要に対応すべく生産が拡大する。炭種別では、一般炭生産が年率 2.9%、原料炭生産が年率 2.7%で増加し、2030 年の一般炭生産量が 48.5 億トンと 2004 年の 2.1 倍に、原料炭生産量が 5.0 億トンと 2004
年の 2.0 倍に拡大する。
４．アジアの石炭需給
アジアでは発電用石炭を中心に石炭消費量が拡大しているが、石炭資源を豊富に有し、経済的に採掘可能な国は限られている。このため、アジア地域全体の消費と生産を比較すると、消費が生産を上回っている。2004 年の消費量と生産量の差（ギャップ）は 1 億 9,400 万トンで、この不足分は豪州を中心にロシア、カナダ、南アなどからの輸入に賄っている。今後、アジア地域においては、石炭消費の増加量が生産の拡大規模を上回るため、このギャップは拡大し、2010 年に2.6 億トン、2020 年に 3.7 億トン、2030 年には 5 億トン以上となる。
５．アジアの石炭輸入
2004 年のアジアの石炭輸入量は 4.0 億トンで、そのうちの 45%を日本が、20%を韓国が、15%を台湾が占めている。石炭は豪州を中心に輸入されており、域内ではインドネシア、中国、ベトナムが主要な輸出国となっている。今後、石炭消費の拡大により石炭輸入量は 2004 年の 4.0 億ト
ンから 2030 年には 8.7 億トンまで拡大し、2004 年の 2.2 倍となる。
アジアの石炭輸入は、これまで主要輸入地域であった東アジアに加え、中国沿海地域、東南ア

ジア諸国、インドでの輸入が拡大する。中国は現在ネット輸出国であるが、沿海地域を中心に輸入が拡大してネット輸入国へ転じる。インドでは拡大する消費を国内生産だけでは賄えず、その不足分を輸入に頼ることになる。その他、石炭資源の埋蔵量が少ないマレーシア、フィリピン、
タイなどでは、今後拡大する石炭需要の大部分を輸入頼ることになる。これまで、石炭輸入の主役であった日本、韓国、台湾の輸入は、台湾の輸入が 2030 年に 2 倍以上に、韓国の輸入が同 1.5倍弱に拡大し、日本の輸入量は微増する。
まとめ
今後、アジアの石炭消費は、発電用石炭を中心に増加し、2030 年には現在の約 2 倍の規模に拡大し、世界の石炭消費の約 6 割を占めることになるが、消費拡大に対して域内での石炭供給が追い付かず、域外からの輸入が拡大することになる。このため、アジア諸地域では、域内での石炭の消費抑制、供給拡大、そして域外からの輸入確保を進めることが重要となる。
なお、本見通しは、日本エネルギー経済研究所石炭グループが行った石炭需給予測に基づくも
のである。

4.

テクニカルツアー 渭河（Wei-He）火力発電所①

概要
場所； 西安市の東方約 20Km（西安市に隣接する咸陽市内）
西安市に電力を供給
設備出力; 120 万ｋW （30 万 kW x 4）
発電所の運営主体； 陝西渭河発電有限公司
出資者； 香港中旅集団有限公司（51%）
西北電力集団公司（30%)
陝西省電力建設投資開発公司（19%）
1 号機の運転開始； 1977 年
現在稼動中； 4 台
3・4 号機（1992 年運転開始）
5 号機（1995 年運転開始）
6 号機（1996 年運転開始）
従業員数； 約 2600 人（内、約 300 人は関連会社）
ロスを減らし、成果主義を取り入れ、全ての面で効率の向上を目指した経営
発電効率； 37.5%
燃料； 中国国内炭⇒ 鉄道により隣接する貯炭場に搬入

冷却塔; 4 基装備
環境設備； 集塵機と脱硫装置を装備

② 写 真【資料集】

1.

セミナープログラム

DAY 1MONDAY, OCTOBER 15, 2007
Opening Session
Chair:
Mr. Jiang Minhua, Director of
TPC/CSEE, President of TPRI (PRChina)
08:30
Opening Remarks
Mr. Zhang Guixing, Vice President of
CSEE (PR China)
08:40
Opening Remarks
Mr. Scott M. Smouse, EGCFE Chair,International Coordination Team Leader,
National Energy Technology Laboratory(NETL), Department of Energy (DOE)
(USA)
08:50
Keynote Address
Mr. Xu Jing, Deputy Director-General,
Department of Development Planning,
Ministry of Science & Technology(MOST) (PR China)
09:00
Keynote Address
Dr. Katsuyoshi Ando, Vice Chairman,
Japanese Committee for Pacific Coal
Flow (JAPAC) & President, Japan Coal
Energy Center (JCOAL) (Japan)
09:10
Keynote Address
Mr. Wu Ruosi, Vice President, China
Huaneng Group (PR China)
09:20
Break
Session 1: Coal Demand Outlook 1
Chair: Mr. Hiroyuki Kondo, Deputy Director,
Coal Division, Agency of Natural
Resources & Energy (ANRE), Ministryof Economy, Trade and Industry (METI)(Japan)
09:30
Policy Tendency of Chinese Coal
Industry Development
Mr. Zhang Yong, Deputy Director, Policy
Research, China National Coal
Association (CNCA) (PR China)
09:50
Coal Demand Outlook in Malaysia
Mr. Hiew Char Loong, Senior Executive(Logistics), TNB Fuel Services Sdn Bhd(Malaysia)
10:10
Coal Demand Outlook in Thailand
Mr. Samerjai Suksumek, Director,
Strategic Energy Policy and Planning
Division, Energy Policy and Planning
Office (EPPO), Ministry of Energy (MOE)(Thailand)
10:30
Discussion
10:40
Tea BreakSession 2: Clean Coal Power Generation
Chair:
Mr. Jiang Minhua, Director of
TPC/CSEE, President of Thermal

10:50

11:10

11:30

11:50
12:00

Power Research Institute (TPRI) (PRChina)
Status and Development of Chinese
Coal-fired Power Generation
Mr. Huang Qili, Academician, Chinese
Academy of Engineering (PR China)
The Role of Technology in Mitigating
Global Climate Change
Mr. Frank Princiotta, Director, Air
Pollution Prevention and Control Division,
Environmental Protection Agency (EPA)(USA)
GreenGen Technology
Mr. Hu Shihai, Assistant President, China
Huaneng Group (PR China)
Discussion
Lunch

Session 3: Clean Coal Power Generation
Chair:
Mr. Huang Qili, Academician, Chinese
Academy of Engineering, (PR China)
13:30
How can environmental regulations
promote clean coal technologies indeveloping APEC economies?
Ms. Jette Findsen, Deputy Program
Manager, Climate Change, Science
Applications International Corporation
(USA)
13:50
Introduction of the First Domestically
Manufactured 300-MW CFB Boiler in
China
Mr. Jin Yaohua, Deputy Chief Engineer,
China Datang Corporation (PR China)
14:10
Clean Coal Utilization in Coal-Fired
Power Plant
Dr. Sungchul Kim, Group Leader,
Combustion & Thermal PerformanceGroup, Korea Electric Power
Corporation (KEPCO) (Republic ofKorea)
14:30
Discussion
14:40
Tea BreakSession 4: Coal Demand Outlook 2
Chair:
Ms. Louise Tamaschke, AssistantManager, Coal Policy Section,
Resources Division, Department ofIndustry, Tourism and Resources(DITR) (Australia)
14:50
Coal Demand Outlook in thePhilippines
Mr. Restituto G. Taganas, Jr.,OIC-Assistant Director, Energy
Resource Development Bureau,
Department of Energy (DOE)(Philippines)

15:10

15:30

15:50

16:10

16:30
16:40

Coal Demand Outlook in India
Mr. K. S. Kropha, Joint Secretary,
Ministry of Coal (MOC) (India)
Coal Demand Outlook in Korea
Dr. Jaeho Kim, Head, TechnicalResearch Institute, Korea Coal
Corporation (KOCOAL) (Republic ofKorea)
Coal Demand Outlook in Chinese
TaipeiMr. Jin-sheng Su, Bureau of Energy(BOE), Ministry of Economic Affairs(MOEA) (Chinese Taipei)
Coal Policy of JapanMr. Hiroyuki Kondo, Deputy Director,
Coal Division, Agency for Natural
Resources and Energy (ANRE), Ministryof Economy, Trade and Industry (METI)(Japan)Discussion
Tea BreakSession 5: Clean Coal Power Generation
Chair:
Mr. Ni Weidu, Academician, Chinese
Academy of Engineering, (PR China)
16:50
Environmental Protection Technology
Status and Development Orientationin Coal-fired Power Plants
Mr. Wang Zhongqu, Director of Safety
and Operation Department, China
Guodian Corporation (PR China)
17:10
Energy Saving of Coal-fired Power
Plant
Mr. Jin Donglai, Deputy Director Safeand Operation Department, China
Power Investment Corporation (PRChina)
17:30
Promotion of Energy Conservation
and Consumption Reduction in
Coal-fired Power Plant with Preserved
Efforts in Adopting Advanced andHigher Parameter Units
Mr. Liu Guoyue, Deputy Manager
General, Huaneng Power International,
Inc. (PR China)
17:50
Discussion
18:00
Adjourn

09:20

09:40

10:00
10:10
Chair:

10:20

10:40

11:00

DAY 2
TUESDAY, OCTOBER 16, 2007
Session 6: Coal Supply Outlook
Chair:
Mr. Restituto G. Taganas, Jr.,OIC-Assistant Director, Energy
Resource Development Bureau,
Department of Energy (DOE)(Philippines)
09:00
Coal Demand and Supply and Policy

11:20
12:00

of Coal Industry in China
Ms. Lu Xiaoyan, Director of Researchand consultation, Information Center,
China Coal Sales and Transportation
Association (CCSTSA) (PR China)(author: Mr. Hao Xiangbin,
Deputy-General, Information Center,
China Coal Sales and Transportation
Association)
Coal Supply Outlook in Australia
Ms. Louise Tamaschke, AssistantManager, Coal Policy Section,
Resources Division, Department ofIndustry, Tourism and Resources (DITR)(Australia)
Coal Supply Outlook in Indonesia
Dr. Ir. Sukma Saleh Hasibuan, Director,
Directorate of Mineral, Coal &Geothermal Program Supervision,
Ministry of Energy and Mineral
Resources (Indonesia)
Discussion
Tea BreakMr. Hiew Char Loong, Senior Executive(Logistics), TNB Fuel Services Sdn Bhd(Malaysia)
Coal Supply Outlook in Russia
Mr. Dmitry Sokolov, International
Researcher, Center for Energy Research,
Northeast Asia (CERNA), Korea Energy
Economics Institute (KEEI) (Korea)
Secondered from Energy Systems
Institute (ESI), Siberian Branch of theRussian Academy of Science (Russia)
Co-authored with Prof. Boris Saneev,
Deputy Director, and Dr. Alexander
Sokolov, Head of Laboratory of Energy
Systems Institute (ESI), Siberian Branchof The Russian Academy of Science(Russia)
Coal Supply Outlook in Vietnam
Dr. Kieu Kim Truc, Dr of Science-Mine
Survey, Manager of International Relation
Business Department, Institute for Mining
Science and Technology, VINACOMIN
Group (Vietnam)
Indonesian Coal Developments
Mr. Hadi Nursarya, Head, Head of
Affiliation Division, Head, Agency for
Research and Development, Ministry ofEnergy and Mineral Resources(Indonesia)
Discussion
Lunch

Session 7: Energy and Water Saving in
Coal-fired Power Plant

Chair:

13:30

13:50

14:10

14:30

14:50

15:10
15:30
Chair:

15:40

16:00

16:20

Mr. Zhao Yi, Vice President, Thermal
Power Research Institute (TPRI) (PRChina)
Application of Low Temperature Sea
Water Desaltion and Cogeneration of
Water and PowerMs. Zhang Jianli, Senior Engineer,
Beijing Guohua Corporation; Co-author:
Mr. Chen Yinbiao, Deputy Chief Engineer,
Beijing Guohua Corporation (PR China)
Low-Risk and High-Return TIFI tm
Technology for Energy Efficiency
Improvement and Pollution Reduction
Dr. Linda Lin, Vice President, Asia/Pacific,
FuelTech (USA)
Evaluation of Energy Consumption
and Analysis of Energy Saving
Potential in Coal-fired Power Plants
Mr. Yu Xinying, Deputy Director, Utility
Technical Supervision. Thermal Power
Research Institute (TPRI) (PR China)
Renovation of Coal-Fired Power
PlantsDr. Tohmei Takekawa, General Manager,
Business Promotion Department, Japan
Coal Energy Center (JCOAL) (Japan)(co-authored with Mr. Li YuSheng and Mr.
Hao Ji Hong of China Electricity Council)
Status of Water Saving and Key
Analysis in Chinese Coal–fired Power
PlantsMr. Yang Baohong, Director of Water
Treatment Technology Dept., Thermal
Power Research Institute (TPRI) (PRChina)
Discussion
Tea Break
Mr. Sun Rui, Chief Engineer, China
Power Engineering Consulting Group
Corporation (PR China)
Control of PM from coal combustion
Dr. Qiang Yao Professor, Head,
Department of Thermal Engineering,
Tsinghua University, Director, National
Engineering Research Center ofIndustrial Boiler and Clean Combustion
Technology of Domestic Coal (PRChina)New Technologies for Power Plant
Water Conservation
Mr. Tom Dendy, Director, Global Market &Application Development, SPX Thermal
Equipment & Services (USA)Integrated Strategy for Efficiency,
Emissions Reductions and Safety for
Coal-fired Power Plants
Mr. Brad Radl, President and Chief

16:40

17:00
17:10

Technical Officer, Taber International LLC(USA)
Problems in Condensate Polishing
System of Direct Air-Cooled Unit and
Its Solutions
Dr. Tian Wenhua, Thermal Power
Research Institute (TPRI) (PR China)
Discussion
Adjourn

Session 8: FBC/USC/IGCC/CCS
Chair:
Dr. Qiang Yao Professor, Head,
Department of Thermal Engineering,
Tsinghua University, Director,
National Engineering ResearchCenter of Industrial Boiler and Clean
Combustion Technology of Domestic
Coal (PR China)
13:30
An overview of post-combustion CO 2
capture at CSIRO
Dr. Paul Feron, CEO Science Leader,
CSIRO Energy Technology,
Commonwealth Scientific and Industrial
Research Organization (Australia)
13:50
Two-stage Dry-fed Entrained Flow Coal
Gasifier
Mr. Xu Shisen, Chief Engineer, Thermal
Power Research Institute (TPRI) (PRChina)
14:10
Fluidized Bed Combustion Power
Plant Technology by Low-Grade Coal
Mr. Yoshiteru Nishie, Adviser to Director(China IPP Business), International
Power Business Department, ElectricPower Development Co., Ltd.
(J-POWER) (Japan)
14:30
Development and Status of Ultra
Supercritical Power Generation
Technology in China
Mr. Zhu Baotian, Chief Scientist, Thermal
Power Research Institute (TPRI) (PRChina)
14:50
Analysis of 3-TPD Coal Gasification
System in Korea
Dr. Hyung Taek Kim, Professor, Division
of Energy System, Ajou University(Republic of Korea)
15:10
Discussion
15:30
Tea Break
Chair:

Dr. Sihyun Lee, Principal Researcher,
Energy Conversion Research
Department, Clean Energy System
Research Center, Korea Institute ofEnergy Research (KIER) (Republic ofKorea)

15:40

16:00

16:20

16:40

17:00
17:10
18:30

Carbon Capture and Geological
Storage Projects in APEC
Dr. Frank Mourits, Senior Science andTechnology Advisor, Office of Energy
R&D, Natural Resources Canada(Canada)GE’s Gasification & IGCC Technology
Application in China
Mr. Jian-Feng Liu, Technical Director,
Application Engineering, China,
GE Energy Consulting (USA)CO 2 Recovery from Power Plant using
Oxy-fuel Combustion System
Feasibility Study & Combustion Test
Results
Mr. Keiichiro Hashimoto, Manager, Boiler& Environmental Group, Research &Development Department, Power Plant
Division, IHI Corporation (Japan)
CFB Technology with Chinese OwnIntellectual Property
Mr. Sun Xianbin, Chief Scientist, Chief
Engineer，CFB Boiler Technology
Department, Thermal Power ResearchInstitute (TPRI) (PR China)
Discussion
Adjourn
APEC EGCFE BUSINESS MEETING(Official EGCFE representatives only)

DAY 3
WEDNESDAY, OCTOBER 17, 2007
Session 9: Flue Gas Cleaning Technology
Chair:
Dr. Frank Mourits, Senior Science andTechnology Advisor, Office of Energy
R&D, Natural Resources Canada(Canada)09:00
Study of Application Issues of SCR on
Chinese Coal Fired Utility Boilers
Mr. Wang Yueming, Assistant Presidentof TPRI; Director, National Engineering
Research Center for Clean Coal
Combustion (NERC) (PR China)
09:20
New Technologies for Emissions
Reduction and Steam Plant Efficiency
Improvements
Mr. Tom Dendy, Director, Global Market& Application Development, SPX
Thermal Equipment & Services (USA)9:40
High-Efficiency SO 2 Removal Using
Activated Carbon Fibers
Dr. Miftahul Huda, Senior Researcher,
Coal & Mineral Technology R&D Centre,
Agency of R&D for Energy and Mineral
Resources, Ministry of Energy andMineral Resources (Indonesia)
10:00
SCR Key Technical Choice for

10:20

10:40
10:50

Coal-fired Power Plants Removal
Nitrogen Oxides
Dr. Zhang Qiang, Head, SCR Group,
Thermal Power Research Institute(TPRI) (PR China)
Why select Air Monitor technology for
total airflow measure?
Mr. David Dunn, Asia-Pacific SalesManager, Air Monitor Corporation (USA)Discussion
Tea BreakSession 10: Power Plant Automation andInformation Technologies
Chair: Mr. Liu Wei, Vice Presiden t,
Thermal Pow er Research Institute(TPRI) (PR China)
09:00
Supervisory Information System atPower Plant Level (SIS) and Its
Development
Mr. Yang Dong, Deputy Director, Power
Plant Maintenance Optimization and
Software Dept., Thermal Power
Research Institute (TPRI) (PR China)
09:20
Development of New Technology andInformationalization in Power Plant
Equipment Management
Mr. Zhong Jindong, Deputy Director
General, Weihai Power Plant (PR China)
09:40
HPI Fuel Centralized Payment
Management System
Mr. Zhao Anxiang, Huaneng PowerInternational, Inc. (PR China)
10:00
Foundation of Digital Power Plant isFieldbus Control System
Mr.Yan Yuping, Scientist, Chief Engineer,
Department of Fieldbus and Control
Technology of Thermal Power ResearchInstitute (TPRI) (PR China)
10:20
Discussion
10:30
Tea BreakClosing Session
11:00
Seminar Summary
Mr. Jiang Minhua, Director, TPC/CSEE,
and President, Thermal Power ResearchInstitute (TPRI) (PR China)
11:10
Closing Remarks
Mr. Scott Smouse, EGCFE Chair,International Coordination Team Leader,
National Energy Technology Laboratory(NETL), Department of Energy (DOE)
(USA)
13:30

Tour (Weihe Power Plant

2. 講演資料※ 各 講 演 資 料 の Copyright は APEC Expert Group on Clean Fossil
Energy(EGCFE)にあり、本報告書では主催者(EGCFE)の許可を得て掲載する。

Day 1 Monday 15 October 2007

APEC Clean Fossil Energy
Technical and Policy Seminar
Harmonious and Sustainable
Coal Power Generation

Opening Session

Day 1 Monday 15 October 2007
Opening Session

Opening Remarks

Mr. Zhang Guixing
Vice President
CSEE(Chinese Society for Electrical Engineering)
PR China让煤电“绿”起来——在 APEC 清洁化石能源技术研讨会上的讲话张贵行2007-10-15

各位来宾、女士们、先生们：
早上好！
在中国电机工程学会、美国能源部、日本经济产业省的指导下，
在中国华能集团公司、中国大唐集团公司、中国国电集团公司、中国华电集团公司、中国电力投资集团公司和中国煤炭工业协会的支持
下，由中国电机工程学会火力发电分会和亚太经济合作组织（APEC）
清洁化石能源专家组共同主办、西安热工研究院有限公司承办的“APEC 清洁化石能源技术研讨会”隆重召开了！本次大会的主题是“和谐可持续煤基发电”。我谨代表本次大会的指导委员会以及中国电机工程学会，对出席会议的各位领导、各位中外来宾、各位专家和
学者、各位代表表示热烈的欢迎！并向你们致以诚挚的问候！
近年来，亚太地区尤其是中国的电力工业发展势头极其强劲，有力地推动了地区和国家的经济大发展。以中国为例，至 2006 年底，发电装机容量达到 62369.82 万千瓦，比上年底增长 20.59%；2006 年
发电量达到 28498.55 亿千瓦时，比上年增长 14.11%。发电装机容量
和年发电量继续位于世界第二。自 2002 年 6 月以来的全国性持续缺
电状况得到了根本缓解，2006 年中国 GDP 达到 21 万亿元，年增长
1

11%，可以说中国电力工业为国民经济的持续发展提供了充足的电
力。在发电装机容量中，燃煤机组的装机容量约占 75%；在发电总量中，燃煤发电约占 80%，充分说明了煤基电力的主导地位。中国一次能源结构以煤为主、其中发电用煤约占一半的国情，决定了煤基发电的主导地位将持续至今后很长的时期。与此同时，我们也看到，我国电力工业由于煤电机组比重高，污染排放也相当大，排放的二氧化硫
占到了全国总量的一半。煤电的可持续性对社会经济的和谐可持续发
展意义重大，因此，依靠技术进步和科技创新，降低煤基发电的能耗
和污染物排放，是我们从事这个事业的人必须为社会承担的重要责任
和使命。
从“十五”期间（2001 至 2005 年）到“十一五”的开局之年（2006年），随着“上大压小”产业结构调整和项目环评审批等政策和规定的实施以及发电技术的进步，我国发电机组的能耗和污染物排放水平已有明显降低：供电煤耗从 2001 年的 385 克/千瓦时，降低到 2005
年的 370 克/千瓦时，再降低到 2006 年的 367 克/千瓦时；污染物排放
以二氧化硫为例，排放绩效从 2001 年的 6.8 克/千瓦时，降低到 2005
年的 6.4 克/千瓦时，再降低到 2006 年的 5.7 克/千瓦时。
而且，在近几年，燃煤机组烟尘排放也在逐年下降，氮氧化物的排放控制日益受到重视；废水排放绩效以年均近 10%的速度在下降，其中 2006 年的废水排放绩效为 0.85 千克/千瓦时，比 2005 年的 0.99
千克/千瓦时下降了 14.1%，且新建燃煤机组几乎全部采用了废水“零排放”技术；在节水方面，干除灰、干排渣、直接空冷等技术在燃煤2机组上得到积极应用，节水技术和水务管理得到加强，节水效果明显，燃煤电厂单位发电量耗水量逐年减少，其中 2006 年的水耗绩效为 3.0
千克/千瓦时，比 2005 年的 3.1 千克/千瓦时下降了 0.1 千克/千瓦时。
尤为可喜的是：今年（2007 年）上半年，全国供电煤耗又降到
了 355 克/千瓦时，发电机组二氧化硫排放绩效降低到了 4.6 克/千瓦
时；在上半年火电（主要是煤电）发电量增长 18.3%的情况下，二氧
化硫排放量同比下降了 5.2%，抵消了其他行业二氧化硫排放增量，使全国二氧化硫排放总量从多年攀升，到今年上半年转向下降，同比
降低 0.88%，减排终于出现了环保“拐点”。
这些成绩的取得更加增加了我们努力使煤基发电向进一步低排放、低耗能进军的决心和信心。可以预测，在其他行业二氧化硫排量
不增加或少增加的前提下，仅通过电力行业燃煤发电机组减少的二氧
化硫排放量，就可实现 2010 年全国二氧化硫总排量消减 10%的目标；烟尘、氮氧化物、废水及其他污染物的减排形势也非常乐观。同时燃煤机组的煤耗、水耗将更加降低。在煤基发电领域，我以为今后我们
主要要做好以下几个方面的工作：
一．上大压小，发展超临界和超超临界机组。
上大压小是提高发电机组总体效率的最快途径，其中以高效率的超临界机组和更高效率的超超临界机组为主流发展方向。在中国，最具典型性的是 600MW 级超临界机组和 1000MW 级超超临界机组。
同时，发展 600MW 级的超超临界机组和 600MW 级以下的超临界机组，将使同容量的发电机组效率提得更高。
3

二．因地制宜地发展循环流化床机组
在利用煤矸石、煤泥、洗中煤及其它难利用燃料方面，优先考虑
使用循环流化床机组，可发挥该类机组的煤种适应性强、自脱硫性能
好等优势；另外，循环流化床机组向着大型化、超临界发展，将提高循环流化床机组的效率和环保程度，拓展其应用范围。
三．继续普及脱硫装置，示范和推广脱硝装置
受益于国家脱硫政策的正确导向，脱硫产业发展迅猛，脱硫装置
在燃煤电厂的安装和投运已经在二氧化硫的减排中发挥了重要作用。
在普及安装脱硫装置以外，逐渐做好脱硝装置的示范和推广，无疑会大大减少燃煤电厂大气污染物的排放。
四．加强水务管理，适当选用空冷机组和采用海水淡化
在燃煤电厂中，进行节水技术的改造，使水务管理向现代化发展，必然会有效地降低耗水量。在缺水地区，空冷机组、特别是大型空冷机组是耗水量少、综合效益比较好的选择。在沿海地区的燃煤电厂中，适宜地采用先进的海水淡化工艺，在实现海水资源的高效循环利用之外，更可大量节约淡水资源。
五．向自动化信息管理要效率
建立发电厂厂级运行过程自动控制系统以及发电集团级信息监
控系统，提高电厂自动化控制、信息管理和运行监控水平，可综合汇总整套机组、整个电厂甚至发电集团的各方面各节点信息，从而有利
于快捷地、有针对性地找到促进机组和发电系统安全、经济、稳定运
行的最佳措施，以提高整体效率。
4

六．IGCC 及多联产关于 IGCC，在全世界来说，这个概念已提出数十年，但总体发展相当慢，发电总量比例非常小。从理论上讲，其发电系统效率较高，
污染物排放较低。不过，欧美国家实际运行的 IGCC 机组在运行中暴
露出了一些不可忽视的问题，其实际效率达不到设计效率，与超超临界机组相比暂时未体现出其明显优势；另外，IGCC 的基础投资较高，对其投资建设也造成很大程度的限制。IGCC 在整个能源系统中的位
置还有待综合考虑和权衡，以作出近期、中期和长期的规划安排。从
长远来看，IGCC 还有一个长处，即可为减排二氧化碳作技术准备，为开创绿色的煤基能源系统打下基础。因此，IGCC 及多联产的发展宜从示范开始，开发和掌握关键的核心技术，积累设计和运行经验，逐步地、有选择性地适当发展。中国华能集团公司即将在天津建设
IGCC 示范电站，这是一个很好的开端和尝试。
七．二氧化碳减排，让煤电“绿”起来
以 IGCC 等关键技术为基础，在煤气化过程中实现氢气与二氧化碳的分离，并对二氧化碳进行捕集和埋存或者商业利用，将改变煤基发电的二氧化碳排放大户的“黑色”形象。前提是要以 IGCC 技术及其他关键技术的成熟来换取投资成本的相对降低，以多联产来获得综合经济效益的相对提高，并以近零排放来达到良好的社会效益。通过示范项目，如华能“绿色煤电”项目，我们将会探索出一条让煤基发电真正“绿”起来的发展道路。在不久的将来，煤电从“黑色”转变
为“绿色”将成为现实。
5以上种种都属于我们要研讨的范围，利用本次会议的机会抛砖引玉，希望大家批评指正。我们召开这次以“和谐可持续煤基发电”为
主题的 APEC 清洁化石能源研讨会，就是要广开思路，博采众长，互相借鉴和学习，希望大家携手合作，共同进取，使煤基发电更清洁、
更高效，为减轻亚太地区乃至世界的能源压力作出努力，为应对气候
变化寻求解决途径，以能源的可持续发展促进社会经济的和谐、可持续发展。这是我们共同为之奋斗的伟大事业，是一件意义深远的大事。
最后，我衷心地预祝本次研讨会圆满成功！
谢谢大家！

6

Day 1 Monday 15 October 2007
Opening Session

Opening Remarks

Mr. Scott Smouse
APEC EGCFE Chair
International Coordination Team Leader
National Energy Technology Laboratory (NETL)
Department of Energy (DOE)
USWELCOME AND OPENING REMARKS
Scott M. Smouse, Chair
Expert Group on Clean Fossil Energy

Harmonious and Sustainable Coal Power Generation
APEC Clean Fossil Energy Technology and Policy Seminar
Xi’an, People’s Republic of China
16 October 2007

Good morning. My name is Scott Smouse, and I chair the APEC Expert Group on Clean
Fossil Energy, which organized this Clean Fossil Energy Seminar. It is an honor to be withyou this morning to open this event The Expert Group is grateful to the Thermal Power
Chapter of the Chinese Society of Electrical Engineering for agreeing to cosponsor and to the
Thermal Power Research Institute for agreeing to host this seminar. I also want to thank ourother sponsors, including all of the five major Chinese utilities and the China National Coal
Association, Japan’s New Energy and Industrial Technology Development Organization(NEDO), and the Japanese Committee for Pacific Coal Flow (JAPAC). I bid a special
welcome to all representatives of foreign governments and companies joining us, as many ofyou have traveled a long way to participate in this seminar. I’m very happy to see so many of
my friends from throughout the region in the audience this morning. And, I want toespecially thank in advance the speakers and panelists for sharing your knowledge andexperience with us over these next 2 days.
The theme of this seminar is “Harmonious and Sustainable Coal Power Generation.” This isa peaceful sounding theme, but the truth is – coal is under attack around the world – often bypeople who do not know where their electricity comes from or what risks or problems
confront other technologies in replacing coal in underpinning the growth of many economies
around the world. Coal faces a significant challenge everywhere that it is produced and used.
Allow me to share with you some of the assaults and setbacks that coal has faced recently
throughout the APEC region and elsewhere.
This year, five planned coal-fired power plants have been scrapped in the U.S. state of
Florida. Two of these were rejected by state regulators while other three were dropped as aresult of pressure from environmental groups around the state. In total, these five plants
would have generated over 4,600 megawatts of electricity, enough power for nearly 3 million
homes. The need for that power did not disappear with the cancelling of these projects – I
fact, demand for electricity in Florida is expected to rise 76 percent by 2030, almost twice as
fast as overall U.S. demand, according to the Department of Energy’s Energy Information
Administration. One of these plants was Tampa Electric’s planned 630-MW clean-coal
IGCC unit that would have been a ‘sister’ to the successful Polk IGCC unit that was
supported under the DOE’s Clean Coal Program. This was despite 11 years of operating
experience at the award-winning Polk plant, which has generated more hours of electricity
from syngas than any other facility in the world. It has been reported that the plant wascancelled because the utility feared it was going to be required by the state to capture andstore carbon dioxide emissions from the plant.
This past August, the Greenpeace ship, Arctic Sunrise, prevented a coal freighter on Lake
Erie, which lies between the United States and Canada, from delivering its shipment of
30,000 tonnes of coal to the 4,100-MW Nanticoke Generating Station, the largest coal-fired
power plant in North America.

Just last month, thousands protested in two provinces in Thailand against plans to build newcoal-fired power plants. Opposition to the proposed plants showed just how badly thegeneral public regards this important energy option in Thailand – despite coal offering thecountry an opportunity to diversify its energy portfolio beyond its current 70% dependence
on natural gas.
You may have heard of an organization named Architecture 2030, which has a goal to reduce
the amount of energy required for buildings. Their website states "buildings are the major
source of demand for energy and materials that produce by-product greenhouse gases." Thefounder of Architecture 2030, the well-respected architect, Ed Mazria, has been quoted assaying, "If you stop coal, you stop global warming. End of story."
In September, the Rainforest Action Network mobilized what was reported as “a moving
picket of noise and resistance to greenwashing and coal-fueled climate change” to protest
and demand corporate accountability at the Bank of America’s 37th Annual Investors
Conference in San Francisco, California.
Last week, the Dutch Advertising Authority ruled that the use of terms such as "clean coal"and "clean fuel" by Dutch energy giant NUON are "misleading." NUON must now stopusing "clean coal" in its print and web adverts. Greenpeace International reported on its
website that "The ruling shows that "clean coal" is a contradiction in terms and that
aggressive marketing of it is nothing more than a desperate attempt by the coal industry to
make itself relevant in the face of climate change." NUON operates the Buggenum IGCC
plant, which has been gasifying 2000 tonnes of coal each day to generate about 250 MW ofelectricity since 1993.
While we are on the matter of the courts, back in 1999, the U.S. Environmental Protection
Agency, eight states, and 14 environmental groups filed a lawsuit against American ElectricPower (AEP), the largest coal-burning utility in the Western Hemisphere, accusing it ofviolating the Federal Clean Air Act and causing acid rain with pollutants from its coal-fired
power plants in Ohio and the Appalachia region. AEP fought the suit for 8 years, but decided
to settle the case last week just before the district court handed down its decision. Tosummarize the settlement: AEP will pay $60 million for clean-up and abatement, $15 million
in damages, and then spend billions upgrading their coal plants by installing SO2 and NOx
emissions control equipment.
Time magazine reported last week that "The people cried out" when Vietnam's government
announced plans to add a second coal-fired generator to an existing plant. Despite objections
from environmental groups, the Asian Development Bank (ADB) last month agreed to fundthe $1 billion, 2,200-megawatt Mong Duong coal plant in northern Vietnam. The article
stated that "Vietnam's leaders believe they have little choice." because "To maintain economic
growth of around 8% per year, the state power company, Electricity of Vietnam (EVN), needs
to double its capacity to an estimated 26,000 megawatts by 2010."
I almost forgot — on September 3rd, activists shut down the Loy Yang power station in
Victoria, Australia, to protest against inaction on climate change by the AustralianGovernment, and against policies that maintain the Australian coal power industry and its
contribution to climate change at the expense of developing renewable energy. The
spokesperson for the Real Action for Climate Change group, which organized the protest,said the action was intended to send a message to APEC leaders who met in Sydney thatweek.
A new public opinion poll by Saint Consulting in the United States, which was released a few
days ago, showed that 57% of American adults oppose construction of new power plants intheir communities. However, maybe this is good news in that 57% is down significantly
from the 74% opposition measured in last year’s survey. Maybe, Americans are finallywaking up to the need for more electric power plants.
All this happening while coal demand worldwide, especially in the Asia Pacific region, is
growing year over year, causing coal prices to be at all time highs. Some are predicting coalshortages in region of up to 100 million tonnes annually by 2020.
It has been said that the world is facing two major energy-related threats: that of not having
adequate and secure supplies of energy at affordable prices and that of environmental harmcaused by consuming too much energy. Meeting the world’s growing hunger for energy will
require massive investments in the world’s energy-supply infrastructure. The International
Energy Agency, in the Reference Scenario projections of their 2006 Energy Outlook,estimated that a cumulative investment of just over US$20 trillion (in 2005 dollars) will beneeded by 2030 to meet future energy demand, with the power sector accounting for 56% of
this total. Most of this investment will be needed in Southeast Asia, which is heavily
dependent on coal.
Coal production worldwide is approaching 5 billion tonnes. According to the IEA, coal use
worldwide is projected to increase by about 60% by 2030. Coal use in China is projected to
double and to increase by 130% in India in a little more than two decades. China, the largest
producer in the world, reported a total coal output of more than 2.3 billion tonnes of coal lastyear, and yet that is not enough to meet its power generation needs. The Xinhua news agency
reported on October 5 that China intends to boost coal output by 400 million tonnes per yearby 2010 by streamlining the industry and opening a string of new "super" coal mine pits.
The use of coal already faces significant opposition at today’s consumption levels, and it willundoubtedly draw more attention in the future unless we take bold steps and make theinvestments necessary to reassure those who have valid concerns about the use of this fuel.
Many are asking why the United States is planning to build about 150 new coal-fired plants
over the next decade, and why China is building a new coal-fired power plant about every
week, and why India is building a new coal-fired power plant almost every month, when weshould be "well on our way" to GHG reductions. The answer is simple – there is no otherviable alternative, from an economic or resource perspective, that can meet the enormous
power needs of both developed and developing countries alike. That, however, does not
excuse us from our obligation to mine and use coal as cleanly as we can.
Coal, and the emissions of CO2 that accompany its use, are in the mainstream of public
consciousness like never before. You may be familiar, and if you aren’t, your children
probably are, with the SimCity computer game sold by the software company, Electronic
Arts (EA). Recently, the global energy giant, BP, has begun working with EA to design
choices for generating electricity in the game, which means considering cost, capacity, public
response, and externalities including pollution. In designing your virtual city, you can choose
between coal, solar, and nuclear power. For many players, the most economic way to powertheir virtual cities is with coal plants, which produce 500 units of electricity and cost 3,000“simoleons,” the game’s currency. It has been reported that coal plants, however, "reduce thehappiness of the city’s nearby citizens, which in turn causes them to produce less tax
revenue." Clearly, when a negative view of coal power generation is “programmed” into ourchildren’s computer games, we must take further action.
The United States and many other nations are not standing around, we are taking action.
The U.S. government has invested more than $20 billion over the past 30 years to develop thetechnologies that we think are needed to assure the continued use of coal. We have met every
challenge that coal has faced in the past, and I’m sure that we will be able to solve coal’s
remaining challenges. In many of our programs, U.S. industry has contributed matching, andsometimes even greater than matching, funding to bring these new technologies into fullcommercial readiness. This reaffirms the government’s view that coal will remain criticallyimportant in our energy future. Our programs encompass every step of technology
development – from bench-scale and computational analyses of new concepts – all the way
up to full-scale demonstration plants. We’ve provided performance and cost information onthese new technologies to legislative and regulatory bodies, such as the U.S. Congress andthe Environmental Protection Agency, to assist them in making the right decisions regarding
the use of coal in the United States.
The Office of Fossil Energy, of which my organization, the National Energy Technology
Laboratory, is part of, is leading the world in developing the technological advances that will
ensure coal’s future, not only in the United States, but everywhere that coal is used. Our
clean coal programs are driven by President Bush’s commitments to increase our energy
security, to reduce our air pollution, and to our reduce greenhouse gas intensity. We are in
the middle of a $2-billion Clean Coal Power Initiative (CCPI) to develop near-zero emissions
coal-based power generation and hydrogen production facilities. Launched in 2004, CCPI is
an innovative 10-year technology demonstration program that fosters more efficient clean
coal technologies that will help maintain coal, our most abundant energy resource, as thecornerstone of our future domestic energy portfolio, particularly for power generation.
If a technology idea is promising, we’re probably already working on it, often throughcooperative international R&D efforts – such as the International Partnership for theHydrogen Economy, the Carbon Sequestration Leadership Forum, and the Methane toMarkets Partnership, and most recently, the Asia Pacific Partnership on Clean Development
and Climate, to name a few. Each of these involves government partnering with industry.
All of our projects are designed to contribute in one way or another to our ultimate goal ofdeveloping a virtually emissions free, coal-based plant that maintains coal’s favorable costadvantage over competing fuels.
There is the potential, if we look ahead several decades, for a range of technologies to beavailable that will allow coal to continue its long history of fueling many countries’ economic
development. Experts say that these technologies, which are have been referred to as zeroemission technologies, can be developed and brought to the market over the next two decades.
However, advanced coal technologies face cost, integration, and reliability hurdles that must
be overcome if they are to be widely deployed. At the early stage of deployment, incentives
will likely be needed in many economies to drive down costs and to help utilities manage therisks associated with new technologies.

The need for such incentives was recognized in the United States, and our Congress, throughthe Energy Policy Act of 2005, authorized the Department of Treasury to provide tax credits
as incentives to move advanced technologies to the marketplace. Last year, we received a
total of 49 applications for these tax credits, which is strong evidence of industry’s interest inthese new technologies. Last November, Energy Secretary Bodman and Treasury Secretary
Paulson announced the awarding of US$1 billion in federal tax incentives to nine companies
to bring about rapid deployment of advanced coal-based power generation and gasification
technologies. Applications for the second round of tax credits are due at the end of this monthfor up to $650 million. With this support, we should see a number of new advanced coalplants start construction in the United States in the next few years.
Today, the United States is moving ahead on our most ambitious clean coal project ever –FutureGen. FutureGen is a 275-megawatt, fully integrated, near zero-emissions, coal-fueled
power plant and research facility that will produce both electricity and hydrogen while
sequestering carbon emissions. The goal is for FutureGen to prove out the new technologies
that will be used in the coal-based power plants of the future and, in the process, gain broad
acceptance of this concept as one solution for future energy and environmental security.
The FutureGen Industrial Alliance, a non-profit consortium of some of the largest coalproducers and users in the world, was formed to partner with DOE on this project. Both the
U.S. government and the Alliance members believe that bringing the FutureGen plant into
reality will not only spur economic development in the United States, but will also serve as amodel for similar plants that will help fuel the world's growing economy. Other countries arevigorously pressing ahead with technological developments to implement "zero emission”
power plants in their own countries – China has proposed GreenGen, Japan has its EAGLE
project, Australia is completing the drilling program for its ‘ZeroGen’ or Stanwell project,
and the German utilities, RWE and E.ON, are well along in their plans for coal-based zeroemission demonstration plants, to name a few.
Earlier, I made mention of the Carbon Sequestration Leadership Forum, or CSLF. The CSLF
is made up of 21 major coal producing and consuming nations, plus the European
Commission, who together account for 75% of the world's carbon emissions. By working
together, the CSLF seeks to develop cost-effective carbon capture and storage technologies
and to address the significant regulatory and economic issues associated with wide-spread
deployment of this technology.
Just how promising is carbon capture and storage? The Intergovernmental Panel on Climate
Change estimated that sequestration could get us more than halfway to the ultimate goal of
atmospheric CO2 stabilization. However, today, the cost to capture and store CO2 is high, but
it could fall to levels that the general public can accept over the next decade or two as wedevelop and demonstrate new processes and gain experience.
The interaction of technology and policy is critically important to coal’s future, which theExpert Group has long recognized in its seminars. While the focus of this seminar is on coal,that doesn’t mean that we don’t think other energy sources aren’t important. Quite theopposite, all energy sources will be needed if the world is to meet its economic aspirations.
In today’s energy-thirsty world, all forms of energy will find their place somewhere inmeeting market demand. In addition to our work on coal, the Expert Group has an active
program on natural gas and LNG. Last year, we completed a study on “The Potential for
Growth of Gas as a Clean Energy Source in Developing APEC Economies” and, through thesponsorship of the U.S. Trade and Development Agency, convened a workshop on the
study’s findings in Guangzhou this past August. We are planning a seminar on LNG public
information and education that will convene in November also in Guangzhou because it isnear China’s first LNG receiving terminal. Because of the importance of natural gas in theregion as a clean energy source is growing, the EGCFE will continue its work in this area.
In closing, I wish to note that, in today’s energy starved world, there is simply no bad form ofenergy. We must find ways to use all forms of energy as cleanly and efficiently as possible.
Every nation needs reliable, affordable, and environmentally sound energy. This goal canonly be reached by industry, academia, and governments working together to take our best
ideas out of the laboratory and into the commercial marketplace. Also, widespread adoptionof new, advanced, innovative technologies can be achieved only if appropriate regulatoryenvironments and market conditions exist, which governments can help create.
No one country can solve coal’s remaining challenges alone – it’s a huge effort. And climatechange is a WORLD problem – which is best addressed through international cooperation. In
developing FutureGen, we deliberately took a partnership approach by inviting not only U.S.
industry and state governments to join with the federal government, but also foreign
governments and industry. Working together to achieve such solutions makes far more sensethan trying to do so alone.
These sentiments were articulated most recently at the Major Economies Meeting on Energy,
Security, and Climate Change. U.S. Secretary of State Condoleeza Rice noted that we must
be committed to working together to address "…..climate change in a way that does not
starve economies of the energy they need to grow and that does not widen the alreadysignificant income gap between developed and developing nations." Echoing her commens at
this meeting was James Connaughton, Chairman of the White House’s Council on
Environmental Quality, who said, "We can be optimistic. The technology pathways are there.
A mix of strategies is what’s going to deliver that – incentives, mandates andpartnerships….."That is why events, such as this seminar, are important as they provide a forum to discuss ourenergy futures. At this seminar, valuable information will be shared that will help us tounderstand each other’s problems and opportunities, and to continue discussing how to meetand balance the many needs of our economies – abundant, affordable energy…..sustainableeconomic growth…..good-paying jobs…..and respect for the environment. In this regard, I
look forward to hearing from our speakers and panelists today and tomorrow on theseimportant issues.
Thank you.

Day 1 Monday 15 October 2007
Opening Session

Keynote Address

Mr. Xu Jing
Deputy Director-General
Department of Development Planning
Ministry of Science & Technology (MOST)
PR China

在“和谐可持续煤基发电” 清洁化石能源技术研讨会开幕式上的讲话
中国国家科技部计划发展司副司长许 倞

各位来宾，女士们、先生们：大家好！
非常高兴参加中国电机工程学会火力发电分会和 APEC 清洁化石
能源专家组（EGCFE）共同主办的清洁化石能源技术研讨会。
这次会议以“和谐、可持续煤基发电” 为主题，很有意义。
能源是人类社会生存和发展的重要物质基础，世界能源消耗总量的
80%以上来自煤、石油与天然气等化石能源，煤炭又占据了亚太地区
化石能源资源结构中的绝对主导地位，研讨清洁煤能源政策，推动清洁高效火力发电技术的应用，对促进亚太地区可持续发展具有重要意义。
经济全球化趋势加速发展已成为当今世界经济的一个最显著的特征。经济发展与资源环境的矛盾日趋尖锐，解决能源可持续供给和保护生态环境已经成为当今世界各国高度关注的焦点和重大战略。
中国政府高度重视经济发展与环境保护问题，早在 1994 年，我国就率先出台了 21 世纪议程，提出了可持续发展的战略。1996 年，
这个战略正式成为国家战略。多年来环境保护、清洁能源问题一直作
为科技工作的重点工作来安排。
“十五”期间，在国家 863 高科技计划，攻关计划和 973 计划中，一共安排了 25 亿元资金，在“十一五”整个国家科技计划安排中，更是把如何解决能源问题、环境问题、应对气候变问题作为科技工作的重要任务，以支撑可持续发展。

中国在《国民经济和社会发展第十一个五年规划纲要》中明确提
出了“十一五”期间单位国内生产总值能耗降低２０％左右，主要污
染物排放总量减少１０％的约束性目标。为了实现这一目标，中国国务院发布和实施了《节能减排综合性工作方案》，同时为了应对经济发展过程中的全球气候变化问题，还发布和实施了《中国应对气候变
化国家方案》。国家科技部适时配合出台了《国家节能减排科技专项行动方案》和《中国应对气候变化科技专项行动》，科技作为实施这
些方案的重要支撑手段。
今年上半年，国内单位生产总值能耗同比下降 2.8％，二氧化硫排放减少 0.88%，化学需氧量排放增幅下降 0.76 个百分点。一年多来，中国节能减排初见成效。但与世界先进水平比较还有较大差距，
节能减排形势仍很严峻，需要进一步依靠科学技术发展的有力支撑，付出更多的努力。
中国政府已将能源和环境列为国家中长期科学技术发展的重点
领域，把全球环境变化监测与对策列为环境领域优先主题。计划经过
15 年的努力，在能源开发、节能技术和清洁能源技术等方面取得突破，促进能源结构优化，主要工业产品单位能耗指标达到或接近世界
先进水平。
在煤炭高效开发和利用方面，重点研究开发煤炭高效开采技术及配套装备，重型燃气轮机，整体煤气化联合循环(IGCC)，高参数超超监界机组，超临界大型循环流化床等高效发电技术与装备，大力开发煤液化以及煤气化、煤化工等转化技术，以煤气化为基础的多联产系统技术，燃煤污染物综合控制和利用的技术与装备等。并在国家 “十一五”能源领域科技计划中重点进行部署，在 2006、2007 年国家科技计划中已经先后启动了“以煤气化为基础的多联产示范工程”、“MW级并网光伏电站系统”、“太阳能热发电技术及系统示范”、大功率风
电机组研制与示范、特高压输变电系统开发与示范、动力煤优质化技术与高效燃煤锅炉技术开发、超临界循环流化床、重型燃气轮机等一批能源领域重大、重点和科技支撑项目。同时还安排了一批氢能与燃
料电池、高效节能与分布式供能、清洁煤和可再生能源技术方向的前
沿探索类专题和课题。必将为中国经济可持续发展、优化能源结构，实现建设资源节约型、环境友好型社会提供有力的科技支撑。
应对能源与环境的挑战，是当今世界各国共同面对的主题，归根
到底是要依靠科技进步和创新。本次会议主题符合当今世界经济发展
趋势，对加强各国在能源与环境领域的国际科技交流与合作，共同研
究和探讨能源与环境领域技术问题，提升能源与环境领域科技创新能力，促进煤基发电技术进步，将会起到积极的促进作用。让我们共同携起手来，加强合作，为亚太地区建立稳定、经济、清洁、安全的能
源供应体系而努力奋斗。
最后，预祝本次会议会取得圆满成功！祝朋友们身体健康！

Day 1 Monday 15 October 2007
Opening Session

Keynote Address

Dr. Katsuyoshi Ando
Vice Chairman
The Japanese Committee for Pacific Coal Flow (JAPAC)
President
Japan Coal Energy Center (JCOAL)Japan

Facing the Challenges
with Undaunted
Determination～Overcoming Environmental Restrictions andResource Restrictions～2007 Clean Fossil Energy Seminar
Jointly Organized by APEC EGCFE and TPC/CSEE
October 15~17, 2007 Xi’an, PR China

Mr. CoalVice Chairman, JAPAC
President, JCOAL
Dr. Katsuyoshi Ando

Ms. Coal

1
The Japanese Committee for Pacific Coal Flow

I. Active Movements to Prevent Global
Warming
The United Nations
Intergovernmental Panel on Climate Change (IPCC)
Report (2007 May)
~stop atmospheric temperature rise to a 2 degree⇒It would be necessary to revert the trend of the world’s
greenhouse gas emission toward a reduction by 2020 at
the latest and halve it by 2050 as compared with 2000.
The panel has urged all countries to take full-scalemeasures without delay.
2The Heiligendamm Summitt(G8)(June 2007)
Former Japanese Prime Minister ABE“Invitation to ‘Cool Earth 50’”
Current level～to half from the current global
greenhouse gas emission⇒all countries

The Lake Toya Summitt (G8) (July 2008) in Hokkaido

3

Fig. 1

Fig. 1 Invitation to Cool Earth 50

4

USA
FutureGen (AP6） ~ to more concrete~
China
vast CO2 emission~proposed a 20% energy saving target until
2020~
Japan
“Long-term Strategy”, “Mid-term Strategy”,“National Campaign”“Innovative technology development”“Innovative Zero-Emission Coal-fired
Power Generation” – Important theme5Fig 2Long-term Forecast of CO2 Emission

6

Fig 3Global Warming Issue◆ Over 2 degree C of global warming negatively affects on the earth with certain scientificuncertainty.
◆ Stabilization of GHG concentration at 475ppm should be kept after 2030 to control thewarming temperature under 2 degree C.
◆ About 10% at 2020, 50% at 2050, and 75% at 2100 of GHG emission compared to that at
1990 should be reduced.

7

(1) Present Situation and Future
Outlook of CO2 Emission Volumes① Signing of the Kyoto Protocol is important as the first step toward taking

action against global warming.
② CO2 reduction effect by the advanced industrial countries with reduction
obligation, is roughly 30% in the total CO2 emission volume. There is alimit to CO2 reduction effect.
③ It is quite certain that CO2 emission volume of countries without reduction
obligation will rapidly increase. Total emission volume is estimated toincrease roughly by 40%.
④ To achieve effective mitigation of global warming, commitment of thecountries with large emission is indispensable. One of those countries is
the United States, the nation with the largest emission level, and others arecountries such as China and India with significant increase in emission byeconomic growth.

8(2) How can a Reduction in CO2 beachieved?
① Both the industrial and the commercial, residential sectors
should establish rigorous reduction targets.
② Each country should specify in a concrete manner its
voluntary “energy saving measures”.
Japan is prepared to expand to the world as a whole
the finance mechanism for supporting developing
countries responding the Japanese proposals andcommitment to the East Asia regarding energy
efficiency.

9(3) Promoting Innovative Technology
Development① It is a fact that there are many who argue that the CO2 reduction targets proposed
today cannot be achieved.
② To achieve this goal, it is necessary to accelerate efforts to establish abreakthrough by way of bold technical innovation and the integration of thevarious technologies.
③ As today’s theme is about “coal power generation”, I would like to focus on thisissue of breakthrough and integration in technologies.
・The issue is also important when we consider the fact that approximately 30% of
the world’s CO2 emissions goes to coal power generation.
・A look at the structure of world power generation shows that coal accounts forroughly 40% and that it has a high share of 80% in the United States and China.
The share of coal in power generation structure has shown an annual growth rateof 3%. However judging from the recent situation of shift to coal in power
generation, I think this rate of coal in power would have been increasing
substantially.
・The fact is that whereas a share of coal in the world’s primary energy wasapproximately 25% at one time, it has risen to 26-27%.
10

TABLE 1
Change of Framework of Power Generation in the
World

Coal

Fuel Input

Oil
Natural Gas
Nuclear
Hydro
Others
Total
Power Generation(Unit: Million Tons Oil Equivalent)
2003Average
2004 Annual Growth
1989 1997 2000 2001 2002 2003 2004
(04/89)Growth996 1,374 1,494 1,547 1,583 1,683 1,803
7.1%
4.0%
42.9% 44.5% 44.3% 45.1% 45.0% 45.2% 45.8%
277
279
282
269
271
273
277
0.0%
1.5%
11.9% 9.0% 8.4% 7.8% 7.7% 7.3% 7.0%
342
556
650
658
704
744
782
5.7%
5.1%
14.7% 18.0% 19.3% 19.2% 20.0% 20.0% 19.9%
507
624
676
692
694
687
714
2.3%
3.9%
21.8% 20.2% 20.0% 20.2% 19.7% 18.4% 18.1%
179
221
226
221
224
227
241
2.0%
6.2%
7.7% 7.2% 6.7% 6.4% 6.4% 6.1% 6.1%
24
36
44
44
43
109
118
11.4%
8.2%
1.0% 1.2% 1.3% 1.3% 1.2% 2.9% 3.0%
2,323 3,090 3,372 3,431 3,518 3,724 3,936
934

1200

1323

1331

1381

1433

1501

5.7%

3.6%

4.7%

3.2%

Source: The Energy Data and Modelling Center, The Institute of Energy Economics, Japan 2007
11

TABLE 2
Outlook of Primary Energy Consumption in the world

Oil
Coal
Natual Gas
Nuclear
Hydro
Biomass and
Waste
Other Renewable
EnergyTotal

Upper:million tons oil equivalent, Lower: proportion
ActualOutlook
Growth Rate
1980
2004
2010
2030
(30/04)
3,107
3,940
4,366
5,575
1.4%
42.8%
35.2%
34.0%
32.6%
1,785
2,773
3,354
4,441
1.9%
24.6%
24.8%
26.1%
26.0%
1,237
2,302
2,686
3,869
2.1%
16.4%
20.5%
20.9%
22.6%
186
714
775
861
0.8%
2.6%
6.4%
6.0%
5.0%
148
242
280
408
2.1%
2.0%
2.2%
2.2%
2.4%
765
1,176
1,283
1,645
1.4%
10.5%
10.5%
10.0%
9.6%
33
57
99
296
6.8%
0.5%
0.5%
0.8%
1.7%
7,261
11,204 12,842 17,095
1.7%
Source: IEA world Energy Outlook 2006

12

④ It is viewed that when general energy efficiency is raised by 1%, CO2 isreduced by 2.5%. Consequently, efficiency improvement is essential task
also for thermal power plants.
⑤ Japan achieved 2.5% improvement in gross thermal efficiency of coal
power generation from 1980 to 2005 through the introduction of thepractical use of SC and USC. In fact, Japan did reach the world highest
efficiency level of approximately 42%. During this period, Japan was alsoable to have technology that leads to extremely small emission levels of
SOx and NOx from coal power stations.

13Fig 4Progress of Generating Efficiency due to the Diffusion of CCT
In Japan, efficiency (gross thermal efficiency) of coal-fired power
generation plants increased about 2.5% since 1980 to 2005, throughpractical application and introduction of SC (Super Critical) and USC(Ultra Super Critical) power generation technologies.

14

Fig 5Emission of NOx and SOx from each country, g/kWh

Source: The Federation of Electric Power Companies of Japan15

⑥ Now development of IGCC, Integrated coal Gasification Combined
Cycle is being developed under worldwide competition. If thechallenges of development of IGCC and also A-IGCC, A-USC, IGFC
and A-IGFC is achieved, and consequently dramatic improvement arepromoted, a 30% CO2 reduction may not be a far-off dream.

16

Fig 6
Outlook of Efficiency of A-IGCC and A-IGFC

17

Fig 7 High-efficiency Coal-fired Power Generation Technologies■ Pulverized Coal-fired (PC) Power Generation Plants Equip Steam Turbine (ST) only.
■ Integrated Coal Gasification Combined Cycle (IGCC) integrates gas turbine (GT) and ST, andrealizes higher efficiency than PC. The efficiency increases by increasing gas temperature at the GT
entrance.
■ Integrated Coal Gasification Fuel Cell Combined Cycle (IGFC) is a ternarily integrated system which
equips fuel cell with IGCC and realizes higher efficiency than IGCC.

PC(USC)

1500℃-class IGCC

IGFC

FC
GT

GT
BoilerST

Gross Thermal Efficiency: 42%
Net Thermal Efficiency: 40%(Reference Case)

GasifierST

Gross Thermal Efficiency: 51~53%
Net Thermal Efficiency: 46~48%
CO2 Reduction: ▲15%

GasifierST

Gross Thermal Efficiency: 60%
Net Thermal Efficiency: 55%
CO2 Reduction: ▲30%

※ HHV basis

18

(4) It is difficult to achieve CO2 substantial
reduction through improvements ingenerating efficiency alone.
◎In this context, Carbon Capture and Storage (CCS), which is capable ofreducing CO2 from fossil fuels drastically, should be evaluated as almost the
only technology. And in this respect, I think we should bring together our
technical wisdom on an international level to develop CCS.

① Since CCS is based on an integrated treatment system comprising “CO2separating and recovery”, ”Transportation”, ”Storage”, it is, therefore
necessary to have a comprehensive commitment to it.
② I also believe that the accumulation of knowledge and experience basedon verification of CCS plays an important role in evaluating theapplicability of CCS.
③ I believe that the integral introduction of a variety of technologies suchas “improvement in generating efficiency”, “responding to the challengeof CCS”, and “co-firing with Biomass” will be key to the realization of
the zero emission goal for coal.
19II. “Serious” Situation in the Supply and
Demand Balance of Steaming Coal
~Looking for Road to the Resurrection of Reliable Coal~
It is no exaggeration to say that the supply and demand balance for all resources is becomingtight on the supply side and that prices are escalating sharply supported by the world’s sustainedboom.
Although coal could not have been an exception to this rule, coal does provide a sense of security
and reassurance in that “Coal can easily be obtained at any time”.
A rise in coal price did occur in around 2003, but was it not the general opinion that supply anddemand would be balanced and controlled?
I suggested 15 years ago that China would become a net importer of coal, but at that time I wasscorned for it.

20

Fig 8 Trend of Steam Coal Price$75.00$70.00$65.00

BJ Spot
Benchmark$60.00$55.00$50.00$45.00$40.00$35.00$30.00$25.00$20.0027-Jul-95

12-Sep-96

6-Nov-97

17-Dec-98

24-Feb-00

5-Apr-01

16-May-02

26-Jun-03

5-Aug-04

15-Sep-05

26-Oct-06 27-Sep-07

21

Fig 9Average CIF Price of Fuels Imported to Japan

Source: The Energy Data and Modeling Center (EDMC), The Institute of Energy Economics, Japan22

Fig. 10 Present situation and predictions for worldwide coal
imports

Million Short tons
12 0 0

10 0 0(1 4%)

南北アメリカヨーロッパ・中東・アフリカ
アジア

160

(10 %)

800(1 0%)

(21%)

89

236

(27%)

76

242

(32%)

600

246

(65%)

400

727

(63%)

571

(52%)

438

200
Australia
In do ne sia
Ch ina1 98 (45 % )
99 (2 3% )9 0( 21 %)Au stralia
In don esia
Chin a2 36 (41 %)13 8( 24 %)
96 (1 7% )Au stralia
I ndon esia
Chin a3 26 (45 %)1 53 (21 %)1 03 (1 4% )

0

2004年

2015年

2030年
Source：EIA International Energy Outlook 2006

23

TABLE 3
Outlook of Coal Supply/Demand in Major Asian Countries(Unit: million tons)
1999

2005

2010

Total major coal producing and Production
consuming countries in Asia
Consumption

1,159.3

1,367.5

1,532.2 1,723.2

1,976.5

1.42.5

1,534.5

1,709.5 1,956.0

2,275.0

Coal Supply Shortage in Asia

▲183.2▲167▲177.3 ▲232.8 ▲298.5(100 million tons oil equivalent)(▲747) (▲681)(▲724) (▲950) (▲1,218)

Australia

2015

2020

Production

255.5

316.7

333.0

353.0

375.8

Consumption

78.8

83.2

86.2

92.3

100.5

Potential for Export

176.7

233.5

246.8

260.7

275.3

-

185.2

195.8

206.7

218.4

Possible Supply from Australia towards Asia
based on the export distination ratio from Australia in 2002
Remarks 1: Major Asian Countries: Japan, China, Korea, Taiwan, Indonesia, Malaysia, Philippines, Thailand, andVietnam (India is not included.)Remarks 2: Calculated on the assumption that 1 kg of coal has the calorific value of 6,000 kcal, and 1 ton of oil isequivalent to 1.645 tons of coal
Source: APERC, “APEC Energy Demand and Supply Outlook 2002”

24

TABLE 4
Coal Production and Trade (export –base) in the World(Unit: Million Tons)
1980

1985

1990

1995

1997

1998

1999

2000

2001

2002

2003

2004

2005 2006e

Growth Ratio
05/80 05/90

Production
(P)
Trade

2,802 3,193 3,498 3,657 3,755 3,695 3,621 3,623 3,787 3,888 4,220 4,634 4,934 5,370

263

345

505

494

543

550

548

615

668

658

709

747

788

2.4% 2.5%815

4.7% 3.2%

9.4% 10.8% 14.4% 13.5% 14.5% 14.9% 15.1% 17.0% 17.6% 16.9% 16.8% 16.1% 16.0% 15.2%

2.2% 2.5%

Steam Coal

125

187

306

304

349

369

365

426

467

469

510

544

566

593

6.5% 4.5%

Coking Coal

139

158

198

190

194

181

184

189

201

189

199

203

222

222

2.0% 0.8%(T)
Trade Ratio(T/P)

Source:IEA Coal Information 200725

(1) Background Factors for Coal Price
Escalation① The present-day situation can be summed up by saying that world coal demandis increasing on such a large scale that supply cannot keep up with demand.
② The factor on the demand side to be pointed out is that too optimistic,
uncertain signals are sent and that confidence is wanting. When supply became
tight in the past, “the LAXT Port” for introducing West USA coal and the“Prince Heart Port” for introducing North American & Canadian coal were built.
Those were at the request of the coal user on the principle of “supply
decentralization”. However they easily withdrew from those ports and evenabandoned LAXT Port in wake of easing of supply and demand. In this way
does it not seem that the important viewpoint inherent in resources, namely, thephilosophy of the long-term resource theory was lacking?
On the other, looking at the supply side it must be pointed out that the long-term
supply and demand predictions were rather poor.

26

③ Regarding the issue of Supply and Demand, it is true that recent theories aredifferent from the cycle theory of prices in the past, like a six-year cycle theory.
But it is most regrettable that theories such as the coal peak theory, the depletion
theory, the theory of the rise of resource nationalism are easily disseminated.
In contrast to these trends I fear that the issue of global warming is bound toaccelerate the suppression of coal use (stopping of coal use) to an increasingly
greater degree.
These trends are bound to hamper future infrastructure development which seems
to be considerably delayed27

(2) The Road to Stable Supply of Coal
① We should reflect on what needs to be reflected on with regard to
efficient mining of finite coal resources (low recovery rate) and theselective mining of good-quality coal, etc. I believe that making efforts
not to repeat these regrettable actions would help the cause of
expanding advanced coal utilization.
② After all the important point is that we should make effective use of thepotential of coal and expand its use in such a manner as utilization of
low-rank coal, recycling of waste, and improvement of recovery rate.
③ Future infrastructure development is also necessary for stable supply of
coal.

28

Fig 11
Coal Resources and Reserves in the World
Coal Total
Anthracite/ Bituminous

Sub-bituminous

Lignite1,513.0
Billion tonnes

554.8
Billion tonnes

683.3
Billion tonnes

Proved Recoverable Reserves

430.9
Billion tonnes

266.8
Billion tonnes

Total
Reserves
149.8
Billiontonnes

847.5 Billion tonnes
2,811.0 Billion tonnes

2005 Coal Production: 5.90 Billion tonnes
R/P = 847.5/ 5.90 = 143.6 years
Source: 2007 Survey of Energy Resources, WEC
Note: The recoverable reserves as of 2025 will be around 115 years if coal demand in the world will be increasing
toward 2025 without any increasing recoverable reserves in the future.

29

Fig 12 Coal Production per Coal Quality and Coal
Consumption of the World
Volume of bituminous coal and anthracite coal is the best of all coalconsumption in the world.

Source: IEA Coal Information 200730

Fig 13
Confirmed Mineable Resources

Technology Development

Coal Price
Present

Present

Present

Present

Confirmed Minerable Resources
Source：Uchiyama 1999
31

Fig 14 Coal Resource Pyramid

Economic

Uneconomic
Source：NSW (1994)
32

《CONCLUSIONS》●In order to respond to the issues on coal today, we should
consider the matter from the view of the coal chain in its
entirety. And it is important that we should integrate“resources”, - “utilization”, - and “environment” and harmonize
these three aspects.
●It is also important all stakeholders in the coal sector shouldhave a common recognition.
For this reason it is important to share information and create
mutual trust.
●Finally, in connection with the problem of global warming,
which is a burning issue, I would like to emphasize that weface the CHALLENGE to be serious about “ENERGYSAVING” and “RESOURCE SAVING”.
33

)
tio
n

til
iza

low
an
sio
no

fu

nd
(E
xp

lit
ya
ua
(H
igh
q

(demand)(supply)

t)
en
m
on
v ir
d
en
an
th
as
wi
re
ce
ga )
ten
in caleinxis
m of soeof(Cn tionsio xaan elar

Utilization

Resources
xp
(E

pr
ice
)

Fig 15 Triangle Concept for Coal Technology Strategy into the
21st Century(Coexistence with environment)

Environment(including naturalenvironment)(Harmony with environment and earth-friendly)34

Ms. CoalThank you very much for your attention.

Mr. Coal

The Japanese Committee for Pacific Coal Flow35

Day 1 Monday 15 October 2007
Opening Session

Keynote Address

Mr. Wu Ruosi
Vice President
China Huaneng GroupPR China在中国电机工程学会火电分会及APEC清洁化石能源研讨会上的讲话乌若思2007-10-15

各位来宾、女士们、先生们：上午好！
今天，我非常高兴和大家一起出席中国电机工程学会火力发电
分会和亚太经济合作组织APEC清洁化石能源专家组联合举办的清洁化石能源研讨会。在此，请允许我代表大会的支持单位（中国华能集团公司、中国大唐集团公司、中国华电集团公司、中国国电集
团公司、中国电力投资集团公司和中国煤炭工业协会）向大会的召开表示热烈的祝贺！向会议的指导委员会（中国电机工程学会、美国能源部以及日本经济产业省）表示崇高的敬意！并向做了大量辛
苦的会议筹备工作的主办单位（中国电机工程学会火力发电分会和亚太经济合作组织APEC清洁化石能源专家组）和承办单位（西安热
工研究院有限公司）表示衷心的感谢！
在中国能源资源结构中，煤炭占据绝对主导地位，一次能源消费中煤炭所占比例接近70%。在全部煤炭消费中，有一半用于发电。
煤基发电是中国电力工业的主角，这一点在可以预见的将来也不会有很大改变。这一特征在发电集团装机结构和发电量方面表现的更
加突出。以华能集团为例，至2006年底，华能集团的发电装机容量1

为5718.5万千瓦（占全国的9.19%），其中燃煤机组的装机容量达到
5229万千瓦，占了91.44%。同时，由于燃煤机组的可用率相对比较高，其发电量的比例比装机容量的比例还要高一些。
提高燃煤发电效率，降低对环境的影响，不仅关系到电力工业
未来的健康发展，更对全社会能源利用水平的提高以及经济、社会
整体可持续发展意义重大。
华能集团公司，作为目前中国最大的发电企业，坚持清洁发展、
和谐发展、又好又快地发展，努力为社会提供充足、可靠、环保、经济的电力，在煤基发电方面坚定不移地走清洁高效发展之路。华
能成功投运了国内首台国产化100万千瓦超超临界燃煤发电机组和
国内首台国产化60万千瓦超超临界燃煤发电机组，率先提出了“绿
色煤电”计划，并启动了国内第一个燃煤电厂二氧化碳捕集试验示范项目。
下面，我简单介绍一下这些项目的情况。
z 100万千瓦超超临界机组及60万千瓦超超临界机组
超超临界燃煤发电机组技术含量高、煤耗低、环保性能好，是国际上燃煤发电机组的重要发展方向。华能集团积极推动了中国在超超临界燃煤发电技术方面的研究和应用。
华能玉环电厂是超超临界机组技术实现国产化的依托工程，规
划装机容量为4台100万千瓦超超临界燃煤发电机组，一期两台机组已于2006年内（11月28日和12月30日）实现双投；二期两台机组正
在紧张的调试中，力争于今年年内（2007年）再次实现双投。玉环2电厂100万千瓦超超临界机组的热效率高达45%，供电煤耗仅为
288.5克/千瓦时，比全国平均水平低70多克/千瓦时；在国内第一个采用“双膜法”海水淡化工艺，建成国内最大容量的海水淡化工
程，制水量为1440立方米/小时，每年可节约淡水资源800万立方米并同步投产脱硫工程。玉环电厂一期工程的建成，在我国电力发展
史上具有里程碑的意义，标志着我国发电技术和电力装备制造水平上了一个新的台阶，为国内超超临界机组的建设、运行、管理积累了经验。
华能集团还于今年8月31日投产了首台国产60万千瓦超超临界燃煤发电机组——华能营口电厂二期3号机组；这是继华能玉环电厂首台国产100万千瓦超超临界机组投产后我国电力工业发展的又一个零的突破。国产60万千瓦超超临界机组的供电设计煤耗为292
克/千瓦时，比全国平均水平低70克左右，与同容量超临界机组比，每年可节约标煤14万吨，相当于每年少排放二氧化硫2572吨；机组耗水率低，与同容量亚临界机组比，每年可节约淡水130万吨，海水淡化装置年节水345.6万吨，并同步实施脱硫工艺和废水零排放。
营口二期国产60万千瓦超超临界机组在国内率先投运，对我国推广该类型机组起到示范作用，有利于实现国产超超临界机组系列化，进一步推动电力工业结构调整，促进电力市场优化发展。
z “绿色煤电（GreenGen）”项目“绿色煤电（GreenGen）”项目是中国华能集团公司于2005年
提出的，该项目计划通过10余年的努力，研究开发并示范推广以煤3气化制氢、氢气轮机联合循环发电和燃料电池发电为主，并能对二氧化碳进行回收和封存的煤基能源系统；大幅度提高煤炭发电效率，使其达到污染物和二氧化碳的近零排放；逐步掌握其核心技术、集成技术和运行技术，形成具有自主知识产权的“绿色煤电”技术，并能够实现其科技成果的迅速转化。
该项目一经提出即受到国内外各方面广泛关注。目前，该项目进展顺利，项目第一阶段计划的自主创新的25万千瓦级煤气化联合循环发电（IGCC）示范电站项目已完成主设备招标工作，即将开工建设，并将于2009年底建成。
z 燃煤电厂二氧化碳捕集试验示范项目
中国第一个燃煤电厂二氧化碳捕集试验示范项目，是由中国华
能集团与澳大利亚联邦科学工业研究组织开展技术合作，在华能北京热电厂建设的年捕集3000吨二氧化碳的试验示范项目。该项目列
入了2007年9月6日中华人民共和国与澳大利亚联邦在悉尼发表的《关于气候变化和能源问题的联合声明》。项目计划于北京2008年
奥运会前建成投运。该项目建成后，将使华能集团具备自主设计烟
气二氧化碳捕集装置的能力，并为大型烟气二氧化碳捕集装置的建设和运行提供依据。同时，华能集团还将成立“北京温室气体捕集与处理实验室”，在燃烧后的二氧化碳捕集与处理等方面开展研
究。
在国内率先启动建设二氧化碳捕集试验示范项目，是华能集团
根据《国务院关于印发中国应对气候变化国家方案的通知》精神，4认真落实科学发展观的具体体现，是支持北京市建设“绿色奥运”的实际行动，有利于我国自主掌握二氧化碳捕集和埋存的核心技
术，有助于中国及全社会应对气候变化带来的挑战。
此外，华能集团还在系统内全面开始了“节约环保型”燃煤发电厂创建活动。除了新建电厂按现代化、高标准进行建设以外，对于老电厂，通过实测和分析机组情况，运用先进成熟技术对老机组的主辅机设备及系统进行节能、节水和环保技术改造，提高机组发电效率，降低二氧化硫、氮氧化物、烟尘、废水的排放水平。这些
实践均已取得了明显的成效，并将取得更大的成效。
华能集团正在努力缩小与国际先进水平的差距，积极赶超国际先进水平。华能真诚地希望与亚太地区的政府机构、企业、以及高等院校、科研机构密切合作，推进先进的高效、清洁煤基发电技术发展，携手共建资源节约型、环境友好型和谐社会。

预祝本次研讨会取得圆满成功！
并祝大家在西安过得愉快！
谢谢！

5Day 1 Monday 15 October 2007

Session 1:
Coal Demand Outlook 1

Day 1 Monday 15 October 2007
Session 1: Coal Demand Outlook 1

Speech 1 PR China
Policy Tendency of Chinese Coal Industry Development

Mr. Zhang Yong
Deputy Director
Policy Research
China National Coal Association (CNCA)
PR China张勇教授级高级工程师,中国煤炭工业协会政策研究部副主任.2000年
10月毕业于清华大学管理科学与工程专业研究生班。1996年任煤炭工业部规划发展司长远规划处助理调研员，2000年9月被授予教授级高级工程师。现任中国煤炭工业协会政策研究部任副主任。曾参加过煤炭矿区总体规划设计、可行性研究、施工图设计、现场施工等，其中两项设计项目获院设计二等奖和一项优秀工程。至今在国家部级以上刊物上发表论文10篇。
组织编写了《煤炭洗选加工“九五”计划及2010年发展规划》，
负责组织编写了《煤炭工业洁净煤技术发展“九五”计划及2010年规
划》（送审稿）。参与了煤炭工业“十五”和现在的“十一五”规划编
制工作。

中国煤炭工业发展的政策趋向
中国煤炭工业协会

※中国政府の要望により、本プレゼン資料は非公表

Day 1 Monday 15 October 2007
Session 1: Coal Demand Outlook 1

Speech 2 Malaysia
Coal Demand Outlook in Malaysia

Mr. Hiew Char Loong
Senior Executive (Logistics)
TNB Fuel Services Sdn Bhd
MalaysiaMr Hiew Char Loong
Mr Hiew Char Loong is currently holding the post of Senior Executive Logistics of
TNB Fuel Services Sdn Bhd (TNBF), a wholly owned subsidiary of Tenaga
Nasional Berhad, Malaysia
He started work with the National Tenaga Nasional Berhad since September 2001.
In the past 6 years, he has served in various field in the Power Generation sector of
TNB;
2002:- Engineer (Performance Planning & Budgeting) –Station

Pasir Gudang Power

2004:- Engineer (Material Management) – Pasir Gudang Power Station
2005:- Engineer (Material Planner, Procurement) – Pasir Gudang Power Station
2006- Present: (Senior Executive Logistics) - TNB Fuel Services Sdn Bhd
He holds a Bachelor of Mechanical Engineer(Hons.) from University of Tenaga
Nasional, Malaysia.

APEC Clean Fossil Energy Seminar 2007
Shaanxi Zhangbagou Guesthouse, Xi’an,Peoples Republic of China
15 - 17 October 2007

Coal Demand Outlook for
Malaysia
A presentation by;
Rusli bin Idrus
Managing Director
TNB Fuel Services Sdn Bhd

CONTENTS
 Capacity Mix in Peninsular Malaysia
 Coal Demand of the Electricity Supply

Industry in Malaysia
 Key Concerns Over Coal Supply Coal Market Outlook
 Internal Challenges in Meeting Coal
Supply Conclusion

EXISTING SYSTEM(as of 20 July 2007)

MAJOR GENERATING STATIONS INPENINSULAR MALAYSIATTPC
GT 3x143MW Gas
ST 1x221MWTELUK EWA
GT 2X34MW Distillate

LEGEND
POWER STATION

Installed Capacity :19,023 MW TNB 33.4%,
 IPP 66.6% (including
KEV, Janamanjung)

Hydro
ThermalGELUGOR
GTJan-03
2x110MW Gas
ST 1x110MWSKSPERGAUPERGAU
4x150 MWBERSIA 3x23 MW
SEGARIGT 3x140MW Gas
ST 1x231.5MW

TEMENGOR 4x82 MW
KENERING 3x40
3x36 MWBlk1,2

SG. PIAH UPPER 2x7.3 MW
MWMW
SG PIAH LOW ER 27.7
2x27.7
27.7 MW3x11 MW1x8 MWCHENDEROH
3x11 MW1x8 MW

GB3
GT 3x143MW Gas
ST 1x211MW
JANAMANJUNG
Conv 3x690MW Coal

PAKA
GT 3x95MW Gas
ST 1x100MWGT 2x87 MW Gas
ST 1x92MWKENYIR
4x100
MWMW
KENYIR
4x100

Blk 1,2,3

Blk 4

ULU JELAI 372MW (2013)
JOR 4x25
JOR
MW
4x25 MWWOH 3 x 50 MW
WOH 3 x 50ODAK
MW 3x1.4 MW
ODAK 3x1.4 MW

KAPAR
Conv 2x300MW Gas
Conv 2x300MW Coal
Conv 2x500MW Coal
GT 2x110MW Gas

YTL PAKA
GT 2x128MW Gas
ST 12x134MWSEPANGJIMAH
GT 1X235 MW Jul -02
Conv
700 MW
GT1x
1X235
MW CoalNov(Jan-02 2010)
Conv
x 700MWMW AugCoal-03(Jul 2011)
CC1+240

Blk 1,2

SOUTH CHINA SEAPANGLIMA POW ER
GT 2X230 (PANGLIMA)
MW GasPOWERTEKST2X2401 x 260
MWOCGT
MWMar -02

SERDANG
GT 2x110 MW Gas
GT 3x135MW Gas
GT 2X20 SANYEN
MW GasGENTINGGT
143 MWGas
Gas
GT 1x38MW
GT
143
MW
Gas
GT 1x20MW Gas
GT 143 MW Gas
GT 3x151MW Gas
ST +251 MW Gas
ST 1x251MW

Sales by Sector(2006)YTL P.GUDANG
GT 2x128MW Gas
ST 1x134MW-PD POWER
GT 4x109.1 MW Gas

STRAITS OFMELAKATUANKU JAAFAR
CC1 715MW Gas
CC2 750MW Gas (Dec 2008)
-02
-03
-

Electricity Generation

ULU TERENGGANU
212MW (2014)-02

CONNAUGHT BRIDGE
GT 4x130MW Gas
GT 2x106MW Gas
ST 1x100MW

System Peak
: 13,458 MW

Note:- Gas Turbine
GT- Combine Cycle
CC
Conv - Conventional Thermal
MW - Installed Capacity

SKS (PRAI)

700 CC
MW1x350MW
Coal SeptGas-

POWERTEK
GT 4x108.5 MW Gas

TENAGA
NASIONALBERHADPAHLAWAN
GT 2X103MW Gas
ST 1X116MWN

SKS TG BIN
Conv 1 x 700MW Coal (Sep 2006)
Conv 1 x 700 MW Coal (Mar 2007)
Conv 1 x 700MW Coal (Sep 2008)

PASIR GUDANG
Conv 2x120MW Gas
GT 2x110MW Gas
GT 2x87MW Gas
ST 1x95MW

CAPACITY MIX BY FUEL TYPE
FOR PENINSULAR MALAYSIA
Capacity Mix 1975
Capacity Mix 1975

Capacity Mix 2000
1980

Diesel(7%)

Hydro(31%)

C o al( 11.4 %)H ydro( 13 .6 %)G a s ( 7 1.9 %)Oil (62%)

Capacity Mix 2007

C o al( 2 6 .7 %)H ydro( 10 %)

Gas( 6 2.9 %)The changing of fuel mix from highdependence on Fuel Oil in 1975 tohigh dependence on Natural Gas in2000 and subsequent introduction oflarge Coal units which is reflective offuel diversification.

Gen Projects Forum

Capacity Mix (%)
30,000

Gas

Coal

Hydro

Fuel Oil & Distillate

Peak Demand
25,19424,184

Total Capacity (MW)25,00020,00018,921

10%

20,371

21,95522,213

9%

9%

11%

11%

16%

33%

33%

32%

31%

21%

9%

17,351

17,571

11%

11%

21%

21%

65%

66%

68%

63%

61%

62%

58%

58%

56%

56%

53%

49%

2004

2005

2006

2007

2008

2009

2010

2011

2012

2013

2014

2015

16,94615,00019,621

22,996

21,771

11%
22%

10%
27%

29%

28%

33%
29%

10,0005,000

0COAL DEMAND FOR POWER
GENERATION IN WEST MALAYSIA(million tonne per annum-Mtpa)

Plant

AnnualCapacity Commissioning
Consumption
(MW)
Year
(Mtpa)

Kapar Ph. 2

600

1988

1.50

Kapar Ph. 3

1000

2001

2.50

Manjung

2100

2002/03

6.00

Tanjung Bin

2100

2006/07

5.50

Jimah

1400

2009/10

3.50

Total

8600

19.00

COAL DEMAND FOR POWER
GENERATION IN EAST MALAYSIA(million tonne per annum-Mtpa)

Plant

AnnualCapacity Commissioning
Consumption
(MW)
Year
(Mtpa)

Sejingkat Ph.1

100

1998

0.50

Sejingkat Ph.2

110

2000

0.50

160

2010

0.50

160

2011

0.50

Lahad Datu
Ph.1
Lahad Datu
Ph.2

Total

530

2.00

Growth in Coal Demand(Million mt/ annum)
25

20

15

10

5

0
2004

Kapar

2005

Manjung

2006

Tanjung Bin

2007

Jimah

2008

2009

Sejingkat

2010

Lahad Datu

Key Concerns Over Coal Supply
Highly dependent on imports
 Logistics infrastructure in key producing
countries
 Coal Quality - Lowering of average CVs
 Environmental concerns – air andwater quality
 Weather Inclement leading to Force
Majeure Volatile Coal and Freight CostKey Concerns Over Coal Supply
Highly Dependence on Imports
¾
¾

¾
¾
¾
¾

Country Diversification (Indonesia, Australia & S. Africa)– to reduce country risk
Load Port Diversification (Kalimantan- 9, Australia - 3,
S. Africa - 1)
Plus/Minus Options (20%) in Coal Purchase Contracts
Long term contracts (5 + 5 years) with option forextension
Staggered contract periods
Coal Pre-Qualification – shorten procurement timeKey Concerns Over Coal Supply
Coal Supplying Countries
Indonesia
Large sub bituminous resource available.
Limited loading ports.
No reliable index to benchmark against.
Unpredictable pattern of the monsoon season
River congestion, shallow rivers during dry season,
Australia & South Africa¾ Geographical disadvantage – higher freight cost.
¾ Bituminous coal resource available.
¾ Index available but not very transparent.
¾ Logistic infrastructure can cause delays in the supply chain,
up to 70 vessels in waiting - waiting time 35 days. (Australia)¾ Capacity balancing system imposed by port authorities –reduce coal supply (Australia)

Key Concerns Over Coal Supply
Coal Quality Assurance








Measures against Deterioration in Coal Quality –blending of bituminous and sub-bituminous coals
Coal quality specification - within Design Coal Range
Coal quality - meets the Coal Quality Rejection Limits
Coal Supply from Reputable Coal Suppliers
Proven suitability through Trial Burn for new coal brandDue Diligence of new coal mines
Independent Third Party Surveyors

Key Concerns Over Coal Supply
Environmental Issues
 Misperception of the public at large on “Clean Coal”
 NGOs are becoming more vocal and getting greaterpublic support
 Additional costs for public buy-in More stringent enforcement of Statutory Regulations
 Changes in Environmental Laws
 Longer period for planting up of Coal coal-fired power
plants Higher costs in coal-fired power plants both capitaland operational

Key Concerns Over Coal Supply
Weather Inclement
Heavy rainfall in Kalimantan – Mines & haul roads
flooding, problem in barging & vessel loading
Heavy Storm in Newcastle and Hunter Valley region –mines flooding, affected railways & ports
Changes in seasonal monsoons
Leading to Force Majeure
Causes the rescheduling of coal supplyKey Concerns Over Coal Supply
Volatility in Coal and Freight Market
Demand outstripping supply - Bullish market for Suppliers
Increasing demand from developing world especially China andIndia. China has become a net importer
Difficulty in nominating vessels
Competition with other commodities – iron ore, grains
Increase in Oil Price has a direct impact on the Coal and Freightcosts especially on operational, production and equipment
Overdependence on US Dollars as the transaction currency –FOREX risk
Difficulty in optimising as-delivered costs
Some coal suppliers have taken advantage of the current highcost of coal, by dishonourably defaulting term contracts where
they have successfully won the bids at lower prices

Coal Market Outlook
GlobalCOAL and JPU Benchmark Coal Market Prices
80.00

70.00
Globalcoal
RB

60.00

Globalcoal
NEWC

40.00
JPU
30.00

20.00

K1 (5900
GAR)

10.00
K2 (5000
GAR)

Date

Source: globalcoal, Platts

7/5/2007

4/5/2007

1/5/2007

10/5/2006

7/5/2006

4/5/2006

1/5/2006

10/5/2005

7/5/2005

4/5/2005

1/5/2005

10/5/2004

7/5/2004

4/5/2004

1/5/2004

10/5/2003

7/5/2003

4/5/2003

1/5/2003

10/5/2002

7/5/2002

US$ / mt

50.00

Coal Market Outlook - FreightSource: SSY

Internal Challenges in Meeting
Coal Supply
Mismatch of Coal specifications and Boiler
designs
Limited flexibility in diverting coal between IPPs
Energy despatch uncertainties – forced outagesof generating units
Stringent Environmental Requirements –changes in Laws
Quality versus Cost – impact on merit order ofdespatch

Conclusion










Coal has become one of the 2 main fuel sources ofpower generation in Malaysia.
The changes in demand and supply of the global coalmarket are affecting the cost and reliability of coalsupply.
Volatile coal and freight market is a great concern tobuyers.
Weather inclement that can disrupt coal supply
severely such as the recent delayed monsoon in
Kalimantan, Indonesia, and the severe storm in the
Hunter Valley region of Australia.
Important to ensure a balance in the generation mix
and therefore available alternatives to coal have to beseriously considered.
Environmental issues will be a main concern in the
future.

VISIT MALAYSIA YEAR
2007

Contact Details
Name: Rusli bin Idrus
Email : ruslii@tnb.com.my
Phone: +603-79568349
Fax : +603-79569221

Day 1 Monday 15 October 2007
Session 1: Coal Demand Outlook 1

Speech 3 Thailand
Coal Demand Outlook in Thailand

Mr. Samerjai Suksumek
Director, Strategic Energy Policy and Planning Division
Energy Policy and Planning Office (EPPO)
Ministry of Energy (MOE)
ThailandMr. Samerjai Suksumek

战略能源政策与计划处处长,
能源政策与计划办公室 泰国能源部

1Mr. Samerjai Suksumek

 Director, Strategic Energy Policy and Planning
Division Energy Policy and Planning Office, Ministry ofEnergy2

AGENDA Coal Situation in Thailand Thailand’s Energy Policy &Power Development Plan 2007-2021 (PDP 2007)
 Coal Demand and Supply Outlook
 Approach to the Promotion of Coal Utilization
 Community Development Fund
 Conclusion

Primary Commercial Energy Consumption
Unit: KBD

2007
2001

2002

2003

2004

2005

2006

(Jan-Jul)

Total

1,203

1,282

1,346

1,450

1,520

1,547

1,595

Oil

560

589

624

686

689

673

668

Natural Gas

431

468

496

518

566

572

614

Coal

62

70

89

94

107

143

168

Lignite

118

118

101

119

125

108

99

Hydro/Elec. Import

32

38

36

32

33

44

46

Share of Energy Consumption in 2001

Share of Energy Consumption in 2007

3%

42%

10%

Hydro/Elec.import

3%

36%

46%

Natural Gas

5%

Coal

38%

6%

LigniteOil

Hydro/Elec.import

11%

Natural Gas

Coal

LigniteOil

Update 09/10/2007

Coal & Lignite Consumption
Unit: Million Tons

2007

2001

2002

2003

2004

2005

2006

Power
Generation

18

17

17

19

19

19

12

Manufacturing

7

8

9

9

11

11

6

Total

25

25

26

28

30

30

18

Share
ShareofofLignite
Lignite&&Coal
CoalConsumption
Consumption
inin2001
2001

Share
ShareofofLignite
Lignite&&Coal
CoalConsumption
Consumptioninin2007
2007
33%
33%

28%
28%

72%
72%

Power
PowerGeneration
Generation(Jan-Jul)

Manufacturing
Manufacturing

67%
67%
Power
PowerGeneration
Generation

Manufacturing
Manufacturing
Update 09/10/2007

Share of Coal Consumption in the Manufacturing Sector

Others 7.4%
Lime 1.5%

Cement

0.1%

73.7%

Tobacco Curing

1.0%

Food Processing

16.3%

Paper & Paper Pulp

POWER GENERATION BY ENERGY SOURCE
Unit: GWh

2007

2001

2002

2003

2004

2005

2006

HYDRO

6,174

7,367

7,208

5,896

5,671

7,950

5,033

FUEL OIL

2,420

1,969

2,434

5,468

7,640

7,808

1,189

DIESEL OIL

248

151

75

233

177

77

18

COAL & LIGNITE

20,296

19,292

19,301

20,404

20,614

24,46818,365

NATURAL GAS

71,22978,91085,68890,28994,46894,39856,874IMPORT &OTHERS

3,503

3,564

3,704

5,220

6,228

7,217

4,168

103,869

111,254

118,408

127,511

134,798

141,919

85,647

TOTAL

Share of Energy Sources in 2006

Share of Energy Sources in 2001
3%

6%

4%

2%

6%

20%

6%
17%

67%

69%
HYDRO
NATURAL GAS(Jan-Jul)

FUEL OIL
IMP.&OTHERS

COAL&LIGNITE

HYDRONATURAL GASFUEL OIL
IMP.&OTHERS

COAL&LIGNITE

Share of Power Generation by Fuel Type (Jan-Jul 2007)

Hydro
Lignite/Coal

6%

Import & Others

5%

21%

2% Oil66%
Natural Gas

Lignite & Coal Supply
Unit: Million Tons

2007

2001

2002

2003

2004

2005

2006

Mae Moh(EGAT)

15

15

16

17

17

16

9

Ban Pu

3

3

2

2

3

2

1

Lanna*

1

1

0.5

0.5

-

-

-

Others

1

1

0.5

0.5

1

1

0.5

Domestic
Supply

20

20

19

20

21

19

10.5

Coal Import

5

5

7

8

9

11

8

Total Supply

25

25

26

28

30

30

18.5

(Jan-Jul)* Lanna ceased mining in June 2005.
Update 09/10/2007

Thailand’s Energy Policy
Framework: To promote energy supply
diversities, emphasizing theuse of indigenous energy
resources, e.g. natural gas.
 To promote efficient
procurement and use ofalternative energy sources.
 To emphasize energy
management to increase thecompetitiveness ofThailand’s production sector
and to stabilize energy
prices through appropriatemonetary, fiscal andmanagerial measures.

Current Strategies:
1. To revise Thailand’s Power
Development Plan (PDP
2007) -- completed May07.
2. To promote the use ofrenewable energy for power
generation.
3. To encourage the use ofclean energy.
4. To promote participation of
the general public in energy
projects.

Thailand’s Power Development Plan 2007-2021(PDP 2007) --Base Case: With Potential Coal-fired Plants
Unit: MWNew Power Plants
Year

Purchasefrom
Neighbour
Countries

Added
Capacity

Total
Power
Capacity Demand

Reserve
Margin
(%)

Gas

Coal

Nuclear

SPPs

2011

-

-

-

-

597

597

34,03727,996

18.0

2012

1,400

-

-

200

-

1,600

35,637

29,625

16.6

2013

1,400

-

-

200

963

2,563

37,58031,384

15.8

2014

1,400

700

-

200

-

2,300

39,88033,216

16.3

2015

1,400

1,400

-

200

380

3,380

42,08535,251

15.6

Total

5,600

2,100

-

800

1,940

10,440

2016

1,400

700

-

200

490

2,790

44,12637,382

16.2

2017

2,800

-

-

200

500

3,500

47,11839,560

15.4

2018

2,800

-

-

200

510

3,510

49,887

41,795

15.4

2019

3,500

-

-

200

530

4,230

52,82844,082

16.3

2020

1,400

-

2,000

100

550

4,050

55,25046,481

16.5

2021

700

-

2,000

570

3,270

58,32048,958

15.3

Total

12,600

700

4,000

900

3,150

21,350

Grand
Total

18,200

2,800

4,000

1,700

5,090

31,790Coal Demand and Supply Outlook
Unit: Thousand Tons

Calendar Year

2006

2007

2011

2016

2021

Supply: Domestic

18,867

19,746

17,525

16,183

15,722

11,472

15,22920,64333,20939,65430,33934,97538,16849,392

55,376

Power

19,304

22,821

22,77528,75127,805

Domestic
Demand Cement

7,724

8,508

10,142

13,615

18,233

Others

3,310

3,646

5,251

7,026

9,338

30,33934,97538,16849,392

55,376

ImportTOTAL SUPPLYTOTAL DEMAND

Update 08/27/2007

Lignite/Coal Demand
60

Million Tons

50

CAGR
7.4%

CAGR
6.8%

50%
42%

40
40%

30
35%

20

6%

6%

11%

10%

10

2008

2010

2012

EGAT

5%

3%

7%

6%

41%

46%

44%

48%

0
2006

CAGR
2.9%

IPP

2014

SPP

2016

Industrial

2018

2020

Share of Power Generation by Fuel Type(based on PDP 2007)
350,000
9%300,000

3%

250,000

10%

3%

GWh

9%

200,000

20%

9%
7%

150,000

15%

16%

20%

100,000
66%

50,000
0
2007

NG

2009

Lignite/Coal

2011

Oil

63%

68%

69%

2013

2015

Hydro/Imp.Electricity

2017

Renewable

2019

Nuclear2021

Coal-fired Power Plants
 The main reason for using lignite/coal as fuel for power
generation is to diversify fuel types so as to increase thepower system security with the minimum generating cost
and to stabilize the power tariffs.
 Currently, the share of coal used in power generation isabout 20%.
 In the future, coal will still play an important role in the
power generation in Thailand.
 EGAT and new IPPs will use more imported coal for
power generation after 2011.
 The use of clean coal technology (CCT) will be required
to enhance the operating efficiency while reducing theenvironmental impact.

Coal and the Environment
 In 1992 pollution problems occurred at lignite-fired Mae Moh
Power Plant, resulting in a poor image of the use of coal.
 In 2000-2001, strong opposition against two IPP coal-fired
projects (i.e. 1,400-MW Hin Krut and 734-MW Bo Nok in
Prachuap Khiri Khan Province), resulting in the fuel-switching
to natural gas and relocation of the two plants.
 To diversify fuel types and to ease the opposition against coalutilization, the Thai government has encouraged the use ofimported coal, together with the use of clean coal technologies.
 Higher environmental and safety standards for coal-fired power
plants are enforced.

Approach to the Promotion of Coal
Utilization
 Past incidents related to coal-fired projects have made itnecessary to improve the strategic approach.
 Promote public participation in coal-fired power projects
to reduce conflict and, instead, to promote harmony &cooperation between host communities and project
developers.
 The establishment of a Community Development Fund
as a requirement of power plants with a PPA of ≥ 6 MW.
 Encourage the use of imported coal in power generationand industries.
 Promote the use of Clean Coal Technology.
Support further R&D in CCT to open up new opportunities
for developing coal-based fuels, which can help utilities tomeet more stringent clean air requirements.

Community Development Fund (CD Fund) According to the (draft) regulations on the guidelines
on the CD Fund establishment,

A power plant located in Thailand with a PPA for a sale of
6 MW of electricity or greater shall pay contributions to
the CD Fund according to the rates specified by the NEPC,
based on the fuel types used.
Fuel Type

Satang/Unit*

Natural Gas

1.00

Fuel Oil/ Diesel

1.50

Coal

2.00

Renewable Energy- Wind/ Solar-- Biomass/ Residues/ MSW

1.00- Hydro2.00*- NEPC resolution 4 Jun07 & approved by the cabinet 19Jun07.
- 100 Satang = 1 Baht

Community Development Fund (Cont.)
 Objective: to allocate the capital for the improvement of thequality of life of the communities and the environment in thevicinities of a power plant to ensure sustainable development.
The CD Fund management & regulation: the “Community
Development Fund Management Committee” will beestablished, comprising representatives from the generalpublic sector, the government sector, the power plant andqualified persons.
Beneficiaries: divided into those living in the “Inner Ring,”
i.e. the areas within 5-km radius of the power plant, and thosein the “Outer Ring,” i.e. the areas beyond the Inner Ring to be
determined by the CD Fund Management Committee.
Enforcement: the Regulations is expected to be effectivefrom 1 Jan 2008 onwards.

Conclusion
 Coal will remain one important fuel in Thailand’s fuel mix
to enhance energy supply security of the economy.
 Providing people with clear and accountable facts andinformation of “clean coal” to create a more positive
attitude about coal, is very important. Public participationin coal project development is necessary.
 The application of CCT by both power generation andindustrial operators will reduce pollution emission fromcoal utilization.
 It is hoped that coal-fired power projects will gain better
acceptance of the general public.
 International cooperation in the development & transfer
of CCT, and continued collaboration & dialogues between
the public and private sectors will be essential.

Thank You

Day 1 Monday 15 October 2007

Session 2:
Clean Coal Power Generation

Day 1 Monday 15 October 2007
Session 2: Clean Coal Power Generation

Speech 1 PR China
Status and Development of Chinese Coal-fired Power Generation

Mr. Huang Qili
Academician
Chinese Academy of Engineering
PR China

HUANG Qili
Professor HUANG Qili, male, born on 25th, January 1941, now is the honorary Chief Engineer of Northeast China
Grid Company Limited. He got the Engineering Doctor’s degree in HOKKAIDO University, Japan, in 1987 and wasentitled as the academician of Chinese Academy of Engineering in 1997. HUANG is the outstanding expert of
Liaoning Province of China. From March 1998, he has been qualified for the national government’s special allowance.
HUANG has engaged in the research in combustion and technical management for a long time, and strived for theapplication of the research results. He dedicated himself to the followings: tackling key problems in large-scale lignite
boiler; stable combustion and regulating operation of the boilers in power plants with low load and oil cutting; Offstoichiometric Combustion of different patterns, emission with reduced NOx, and equal distribution of pulverized
coal. He also organized some scientific researches and engineering applications which are in the domestic leading
place, such as quick-close valve of large-scale steam turbine. In recent years, HUANG hosted, and participated 15 key
national strategic consulting projects which were organized by Chinese Academy of Engineering, such as “Chinese
energy development strategy and key issues in the ‘11th five year’ plan”, “the best technical and economic way to
reduce SO2 emission, as well as the evaluation on composite benefits” etc. He is currently hosting projects: “strategic
research in the development of Chinese renewable energy” .
HUANG was given 32 different-level awards for scientific development, including state level, provincial &ministrylevel, and Northeast China Power Group level. HUANG got one patent, published more than 70 technical papers, andedited Handbook of Electrical Engineer, Handbook of Safe Technology for Boilers’ Pressure Container. He alsojoined the editing team for Handbook of Practical Technology in Fossil-fired Power Plant. He is now in the editing
team for China Electric Engineering Canon.

1The Development of Coal-fired Power
Generation Technology in China

Academician. Qili Huang
TPC CSEE
EGCFE APEC
Xi’an
Oct.15, 2007
2

CONTENT
1. Development of Power Industry in China
2. (Ultra) supercritical Units and CFB
3. Control of Thermal Plant Pollutant
4. Development Direction of Thermal Power
Generation Technology
3Structure Characteristic of Primary
Energy in China







The total coal resource is estimated to be 5.6 trillion tons, including 1
trillion tones are proven reserves, which takes 11% of the global
resource. Meanwhile, China’s oil resource and natural gas resource aresharing 2.4% and 1.2% of global resources separately;
Rich in coal, poor in oil and lack of gas is the characteristic of China’s
primary energy structure. 70% energy consumed in energy production
and consumption comes from coal. The leading position of coal in
China is unchangeable in following 30 to 50 years;
The coal leading energy structure cause severe environmental pollution;
In 2006, the national coal production amounted to 2.325 billion tones,
1.2 billion tones of which (over 50%) were consumed by power
generation and CHP.
4

Development of Installed Generating Capacity
Year

Newly Installed,
MW

Total Capacity,
MW

2001

19166

338487

2002

18084

356571

2003

34837

391408

2004

49292

442387

2005

66000

517185

2006

1011706220002007

95000(forcasting)

720000 (forcasting)2010

800000－850000(forcasting)2020

1100000-1200000(forcasting)20072007-1010-23

5

Characteristics of China’s Power Industry¾

Grid Companies: East China Grid Company Ltd., Central China Grid
Company Ltd., North China Grid Company Ltd., China Southern Power
Grid. These companies own over 100 GW total installed capacity;¾Power Generating Groups: Huaneng Group, Datang Group, HuadianGroup. They own over 50 GW total installed capacity;¾

Fast development of large power plants: by the end of 2006, 144 over
1000MW thermal plants, 23 hydro power plants, 4 nuclear plants, whichtake 48.5% of the national total installed capacity;¾

Booming of large units: Thermal power plant – 1000 MW, Tianwan
Nuclear Power Plant – 1060 MW, Hydro Power – 700 MW, Wind Power
Plant – 2 MW/1.5 MW;¾

Demonstration Projects: UHV AC/DC Power Transmission Projects
20072007-1010-23

6

“Commanding Points” of Power Industry
Power Plant

Capacity

Qinbei

600MW, manufactured domestically,

Date of Put into
Operation
11/23/2004

Yuhuan1000 MW, manufactured domestically,

11/28/2006

Zouxian1000 MW manufactured domestically,

12/04/2006

Tuoketuo

8*600 MW, manufactured domestically, 08/21/2006

Huaneng,Shanghai
Lingao400 MW, NGCC

TianwanThree Gorge
20072007-1010-23

06/15/2006

990 MW nuclear power generating units, 05/28/2002
imported
1060 MW nuclear power generating units,05/17/2007
imported from Russia
14*700 MW

07/21/2005
7

Installed Generating Capacity Structure in2006 and Plan for 2010
1.3%

0.4%

20.6%

Thermal: 484.05

Hydro：

128.57

Nuclear:11 Plant 785Million KW
80 Plant
230 Million KW

WindMillion KW
Million KW

Installed Capacity (2006):
622 million KW

77.7%
1.2% 0.6%

0.7%

Planned Installed capacity(2010): 840 million KW

22.6%

: 593
Thermal

4.3%

Million KW
Natural Gas： 3600
Hydro
: 1.9
Million KW
Nuclear : 1000
Million KW:
500
Million KW
WindMillion KW:550
Biomass

70.6%

Million KW

8

Average Coal Consumption of Thermal
Power Generation Unit
410
392

g/kW h

390
370
370

366
355

350
330
310
2000

2005

2006

2010

年
9

g/kWhThe Coal Consumption of Coal-fired Units in 2006
（Average Loading Coefficient: 78％）
350

340.3
340

330

338.2

328.9

328.0
326.2

320

317.6

310
al
al
al
ge
ical
r ag eS ub critic
percritic
WAver asu bcr itic 370MW subcr it
MWA ve
u
W
0
M
W
S
0
M
7
M
0
0
3
W
5
0
9
0
M
3
－
6
0
0
3
3
60
30035050 0

10Challenge for China Power Industry－1
Development & Energy Consumption：
Net coal consumption, electricity transimission loss, water
consumption per installed generating capacity of thermal
power plant are 30~40 g/kWH, 2.0%~2.5% and 30%~40%
higher than the global advanced level separately. Becauseof this, 120 million tones extra coal, 35 billion kWh extra
electricity, and 1.5 billion m3 extra water is consumed
annually¾ Self-energy consumption (electricity used by service
power and transimission loss) accounts to 12.39% of theconsumption of whole society¾

20072007-1010-23

11Challenge for China Power Industry－2
Development & Environment:
In 2005, SO2 emission from power industry (13.28 Mt)
account to 52% of the national total amount, 58% higher
than the level of 2000;¾ 53000 MW power generating units installed the De-SOx
equipments, 13.8% of the total unit capacity. The ratio in
2005 was 14%;
¾ De-NOx is on the initial stage；¾ Problems of CO2, heavy metals, PM need to be solved.
¾

20072007-1010-23

12Energy and Power Industry Development Strategy

20072007-1010-23

Efficiency _ base, Energy saving _ priority



Coal – basis, Development - diversifiedProtect the ecology and environmentStructure optimizing, energy saving andemission reduction
13

“11th Five-years Plan” Outline of National
Economy and Social development
Energy strategy:
–
–
–
–
–
–








Priority: conservation and saving,Standing feet: domestic,
Basis: coal,
Development: diversified,
Optimize: production and consumption structure,
Build: stable, economic, clean, and safe energy service system

Promote the development of thermal power optimally, with the adoptionof large scale, high efficiency and environment protection units.
Construct large scale USC power station and air-cooled power station
Promote clean coal generation technology, construct 600 MW CFB andinitiate the IGCC project
Encourage the development of pithead power plant, and build large coalfired power basePromote the development of natural gas generating power, and eliminate
lagging small scale unit expeditely
Develop hydro power orderly on base of environmental protection, andpromote the nuclear power development actively
14

Accelerate the Development of Clean Power Technology¾ Develop: Coal-fired, energy saving andemission reduction electricity generating
technology¾ Promote: Quantity and quality control ofcoal-fired pollutants¾ Strengthen: Structure adjustment ofunits and generating energy

20072007-1010-23

15

Development of (Ultra) Supercritical
Units in Chinaz Efficiency of SCU is up to 40%～42％， 2％～3% higher thansubcritical units with the same capacity; the efficiency of USCU is up to
43%～45％， 3％～4% higher than supercritical units with the same
capacityz Through technical import, China has got the technologies of design,
manufacture and operation of USCUz (U)SCU is one of the direction of coal-fired generation technologies.
Gradually increasing the proportion of (U)SCU is of great strategic
significance to the sustainable development of China’s power industry
16

Development of Coal-fired(Ultra) Supercritical Units in Chinaz By the end of 2006, more than 40 (U)SC Units (30GW) have put into operation，among ofthem we have 3 USC Units and each has the capacity of 1GW
z The design coal consumption of USC Units of 1GW is 291～292 g/kWh, which has reached
the international advanced level.
z According to incomplete statistics, more than 150 ultra super critical units with thecapacity from 600 MW to 1,000 MW have been installed, being construction in process, orbeing placed order. Among them, 4 ultra super critical units with the capacity of 1,000 MW
have been put into operation, more than 40 ultra super critical units with 1,000 MW
capacity and more than 10 ultra super critical units with 600 MW capacity have gotten the
project bidding.
z It is required to use (Ultra) Supercritical units with the capacity over 600 MW if possible
17

The Main Design Index for 1,000 MW USC
Installed or Construction on Process in China

PlantsHuanengYuhuanHuadianZhouxian

GuodianTaizhou
Shanghai
Waigaoqiao(phase 3)

Capacity

Steam parameters

Manufacturers

4×1000 MW

26.25 MPa
/600 ℃/600 ℃

哈锅（Mitsubishi ）上汽（Siemens）

2×1000 MW

25 MPa/600 ℃/600 ℃

东锅（Hitachi ）东汽 (Hitachi ）2×1000 MW

25 MPa/600 ℃/600 ℃

哈锅（Mitsubishi ）哈汽（Hitachi）

27 MPa/600 ℃/600 ℃

上锅（Alstom ）上汽（ Siemens）

2×1000 MW

Guaranteed
efficiency of
boiler,%Guarant
eed heat
consumption ofturbin,kJ/kWh

93.65%

7316

93.8%

7354

93.66%

7366

93.6%

7320
18

The Typical Supercritical Units in Chinaz

2×600MW SC units, import by Huaneng Shidongkou Ⅱpower plant¾¾¾

Put into operation in 1992
Efficiency(2006): 307.5 g/kWh
The best super critical units in Chinaz

2×600MW SC units, installed in Huaneng Qinbei power plant

¾
¾
¾
¾

Put into operation in 2004
The first super critical units made in China
steam parameter: 25 MPa/566℃/566℃
efficiency reached 310.8 g/kWh in 2006z

2×900MW SC units, import by Shanghai Waigaoqiao Ⅱconstruction¾¾

were put into operation in 2004
efficiency reached 306.9 g/kWh in 2006

19

Operation Data of Huaneng Yuhuan
2x1000MW USC Units
Performance
examination index

Unit 1

Unit 2Gross coal consumption，
g/kWh

270.6

271.6

Net coal consumption，
g/kWh

283.2

283.9

Auxiliary electric
consumption rate，%

4.45

4.43

NOx，mg/m3

270

288

SO2，mg/m3

17.6

18.1

Dust，mg/m3

39

34

20

CFB TechnologyzInternational advanced level in CFB technology including research, design,and manufacturez

210 MW CFB boiler with our own independent intellectual property rights
has been put into commercial operation in Jiangxi Fenyi power plantz

330 MW CFB boiler with our own independent intellectual property rights
has started in Jiangxi Fenyi power plant, which marked large scale CFB
boiler technology reached international advanced levelzCompact extended dust feedback heat exchanger with our own independent
intellectual property rights, was installed in large scale CFB boiler：¾ It uses air control technology, the first application in the world, has advancemechanical control method than other countries¾ Dust feedback controller and extended exchanger were designed all in one; it hascompact structure and mellifluent layoutz

Slag cooler and primary air fan installed in this CFB have more advanced
performance than abroad
21

210MW CFB Boiler in Jiangxi Fenyi（Commissioning）
z Designed by TPRI and Ha Er bin
Boiler Companyz Passed 96 hours commissioning teston July 7, 2007
zStable running and have achieved
design indexes
zMain steam flow rate: 670/h
zSteam parameter: 13.8 MPa/540/540℃
zEfficiency: 91%
zSO2 discharge: 400mg/m3
zNOx discharge: 250mg/m3
22

330MW CFB Boiler in Jiangxi Fenyi(Constructing)z The first Chinese-made 330MW CFB boiler has
started in Jiangxi Fenyi in Nov.16, 2006
z The largest CFB boiler in China and it has
independent intellectual property rights
z Invested by China Power Investment Corporationand other companies ; the grass investment is 1.29
billion RMB
z Will be completed by October 15 in 2008, Jiangxi
Fenyi Corp. will become the largest demonstration baseof China-made CFB boilers and will have total installedcapacity 640MW at that time.
23

Research on 600MW Supercritical CFB
z Qinghua University, TPRI and other companies are in the research work
under the support of MOSTz Three boiler companies in China have raised respectively their CFB
technologies development programz The research priorities of supercritical CFB：
¾ Distribution rule of density of heat flow rate
¾ Uniformity of gas-solid distribution in 6 separators¾ Water dynamic behaviors¾Heat transfer crisis of water-cooling-wall¾Diffusion issue of coal feeding in big cross-section chamber¾ Penetrability issue of secondary wind
24

The Control Technology of SO2 Emissionof Thermal Power Plant


The limestone/gypsum wet flue gas desulphurization method is themost widely used measure in thermal generating plant with unit
rating 300MW and above. Plants with unit rating 100~300 MW
partly adopt dry lime flue gas desulphurization method, and a few
coastal plants adopt the desulphurization technology by using
seawaterOver 90% desulphurization equipments are manufactured
domestically, with the desulphurization efficiency reaches 90~95%Some companies have gained the mainstream desulphurization
technologies with independent intellectual property rights. The
project general contract capacity of these companies can basicallymeet the requirements from national thermal power plant
constructions.
25SO2 Emission Situation in China
3000
2589

2549

万吨

2500

2294

2255
1995

2000
1500

1200

1000

1300
1000

637

500
2000

2004

2005

2006

2010

z In 2005, the total SO2 emission of China amounted to 25.49 million tones, 27% higher
than the level in 2000, and made China rank the first on the global emission list. SO2from coal-fired power plant contributed over 50% of the total amount of China.
z The total amount of SO2 discharge will be controlled within 23 million tons by 201026

Installed Generating Capacity withAssorted Desulphurization Equipment
60000
Total installed thermal power generating capacity

50000

48405

Capacity with desulfurization

38400

40000
31932

32900

30000
20000

15000

10000
650

2400

0
2000

2004

5300
14％

2005

30％

2006

27

The Plan for SO2 Pollution Control
 General goal of “11th Five-years Plan”: Reduce 10% of SO2 emission,compared to 10th five-years level.
¾ Accelerate the construction of desulphurization system. Newly constructed coal-

fired plant must install desulphurization equipment as standards require.
Strengthen the construction of desulphurization system in both existing and newly
plants¾137 MW generating units with desulphurization systems will be installed, 211

projects and 4.9 million tones SO2 reduction in total. The total amount of SO2
emission of coal-fired power plants would reduce to 5.02 million tones in 2010,
61.4% lower than the level of 2005.
¾The total amount of SO2 emission will be controlled to within 23 million tons by

2010
28

NOx Emission Situation of Thermal
Power Plant in China
×104ton

1000
850
800
650
600

469

536.8

400
200
0

2000

2002

2004

2006

Year

29

Technology route in controlling NOx emission

In purification

In combustion
Generation 1: boiler burning optimization

SCR

LEA

SNCR

BOOS

SNCR＋SCRBBF

LNB＋Fuel Reburn＋SNCR

FGR
Generation 2：Staged-Air combustion
Classified in Burner
LNB(GenerationⅠ)
Classified in furnace
OFA

30％～50% of NOx emission can be
reduced by control in combustion

Generation 3：Staged-fuel combustion
LNB (GenerationⅡ)
Fuel Reburn
LNB＋COFA＋SOFA
Generation 4：Integrated methodz 30～50％ of NOx emission can be
reduced by SNCRz Over 80% of NOx emission can be
reduced by SCR, even highest at
95%，NOx emission can becontrolled under 50mg/m3
30

NOx Control in Thermal Power Plant-1
 Series of low NOx burners are widely adopted to control theNOx emission in subcritical boiler with capacity rating from
300 to 600 MW, some of which simultaneously adopted furnace
air classification burning technology (OFA, over fired air)
¾

¾
¾
¾

The NOx emission of bituminite boiler is about 600~700 mg/m3 (tohigh volatility bituminite coal, it can be controlled to below 550
mg/m3)The NOx emission of lean coal boiler is about 800~1000 mg/m3
The NOx emission of anthracite boiler is about 1100~1300 mg/m3
It can’t meet the requirements of “Emission Standard of Air
Pollutants for Thermal Power Plants. (GB 13223-2003)”
31

NOx Control of Thermal Power Plant-2

Most of the newly constructed USC units rating of 600 MW and above installed
the international advanced low NOx burner, and simultaneously adopted air
multi-staging burning technology (e.g. COFA, SOFA)
–

–

–

–

At present, the designed NOx emission of newly constructed 600 MW SC
units and 1000 MW USC units is about 300~400 mg/m3.
To meet the advanced technical standards of NOx emission of coal-fired
power plant of EU, UK, Germany, Japan (200 mg/m3), SCR fuel gas deNOx equipments with higher investment and operation cost need to beinstalled.
By the end of 2006, SEPA has approved about 50 MW installed
generating capacity with fuel gas de-NOx equipments.
It’s estimated that in 12th five-year period, SCR method will be developed
as current FGD method.
32

The Design Concept of the Fourth Generation of Low NOx
Combustion Technology: Integreated De-NOx System

 Lectotype design for coupling furnace chamber Precise control of environment friendly and economic of coal powder Precise control and balanced distribution of wind volume and coal

 Low NOx burner with double air-fuel classification

 Deep air classification in furnace

 Goal: Control the NOx emission of bituminous lump coal (e.g.

Shenhua coal) within 200 mg/m3 through primary burning

33

High Efficiency and Environment-friendly are Two Main
Subjects of the Development of Power Generation
Technologies
High efficiency– Adopt new technologies to improve the efficient of energy
transformation, transfer, and utilization– Adopt efficient energy conservation and saving measures– Adopt new technology to improve production management
 Environment-friendly– Determined by coal’s leading position in China’s energy
structure– Develop clean coal technology– Develop GHG (mainly CO2) reduction technology
34

Optimizing the Energy Structure - 2006
Thermal Power:¾ Hydro-power：¾ Nuclear power:¾

GTCC ：¾ Wind power ：¾ Bio-power：¾¾

PV power：

20072007-1010-23

484 GW (77.82%)
128.6 GW (20.67％)
Constructing/constructed 16GW,
Operating 7 GW (1.13%)
15.48GW
2.599 GW ( >1MW, 365）
1.9 GW
380 MW

35

Higher Share of SC Parameters, Large Capacity Units
1990: 600MW, 2% of the thermal installed capacity;¾ 2005: 3000MW+, 44％ of the thermal installed capacity;¾ 2005: 116 thermal/hydro power plant with capacity of
1000MW+, total capacity amounts to 192930MW,
sharing 37.5% of the national total capacity, and42.01% of national electricity production;¾ 2006: 80% of the newly put into operation units arewith the capacities above 300, 600, 1000 MW;¾ The net coal consumption was 366 g/kWh in 2006,
while the number in the first quarter of 2007 was
356g/kWh;¾ High efficiency SC unit is taking the leading role¾

36

Actively Develop Large-scale Units
and Limit the Small Onesz Compared with 600MW SC unit, coal consumption of small thermal power units withthe capacity of 100mw , 50mw and below is 100 to 150g/kwh higher.
z Currently, total installed capacities of single-unit below 100mw amount to 115,000MW;
which consume 400 million tons coal and discharge 5.4 million tons SO2 every year
z If calculate with 100g/kwh of coal consumption difference and 5500h/y of running
hours, they will cost 6000 tons more standard coal. If calculate with 150g/kwh of coalconsumption difference, they will cost 9000 tons more standard coal. If close half of them,
30~45 million tons standard coal will be saved.
z In the next 4 years, more than 50,000MW of small-scale coal-fired units, 7000MW to
10,000MW of oil-fired units will be closed. It is not going to launch any more new projectof small-scale thermal generating electricity. In such way, 50 million tons standard coal
will be saved and will reduce 1.6 million tons SO2 emission each year.

37General Development Trend of
Thermal Power Generating Technologyz Single-unit capacity will be increasing continually andparameters will unceasingly improvedz The environment-friendly unites that adopted clean coaltechnologies will be widely usedz Energy conservation and saving technologies will be devoted
more attention increasingly
z Informationization and automation of electric power generation
will increasingly improved38

Development Trend of New Installed Unitsz Mainstream technologies ——super critical, ultra super critical– High efficiency dedusting devices (baghouse filter, high efficiency ESP,
Hybrid filter combined with ESP and baghouse)– High efficiency flue gas desulphurization devices (mainly with wet
limestone scrubber)– Low NOx combustion system, part of them adopt SCR or SNCR
– Air cooling technology is adopted in water lacking areaz Subsidiary technology: CFB, mainly used in:– Desulphurization with medium or low sulfur coal combustion, NOxdischarge is controlled at the same time
– Adopt low quality, nonflammable and easy-slagging coal, such as washingcoal gangue, peat, low-volatile blind coal, low ash-melting coal.
– Peak-load regulation unitsz Demonstration technology: integrated generation combined cycle (IGCC)
39
power generation units

IGCC


High efficiency

“Cleanest Coal Power”

Good fuel adaptability, resource recovery of highsulfur coalWater resource conservation

Experience accumulated from years design andmanufacturingBase for further “GreenGen”

20072007-1010-23

40

Planned IGCC Projects
Power Company

Capacity,MW

Location

Current Stage

Huaneng Group

1*250，1*400

Lingang, Tianjin

Feasibility Study (Finished)

Datang International

2*400

Shenyang, Liaolin

Feasibility Study (On process)

Datang International

2*400

Fangshan, Beijing

Feasibility Study (Beginning)

Datang International

2*400

Dagang, Tianjin

Feasibility Study (Beginning)

Datang (Hunan Branch)

2*400

Shenzhen,
Guangdong

Planning

Datang (Hunan Branch)

2*400

Huizhou, Guangdong

Planning

Guohua Electric Power

2*400

Wenzhou, Zhejiang

Feasibility Study (Beginning)

Guohua Electric Power

4*400

Shanghai

Feasibility Study (Beginning)

China Power Investment Corp

2*400

Langfang, Beijing

Feasibility Study (Approved)

China Power Investment Corp

2*200

Chongming,
Shanghai

Planning

Huadian Group

1*200

Banshan, Zhejiang

Feasibility Study

1*120

Dongguan,
Guangdong

Feasibility Study

20072007-1010-23

Dongguan Tianming Electrical
Power

41

“GreenGen” Project
Prospected Index：¾ Efficiency：

55－60%¾ Heat Power Cogeneration: thermal efficiency: 85~90%¾ SO2、NOx ： < 20mg/Nm3¾ CO2：

separation rate: >80%

¾ PM2.5 & Hg： removal efficiency: >95％
¾ Cogeneration Products：Syn-Gas、H2、Coal chemistry
products
20072007-1010-23

42

High Efficiency and Clean Cogeneration System“GreenGen”

20072007-1010-23

43

Technical Development Trend of CO2
Emission Reducing
1.

2.

3.

Improve the energy transforming, transfer and utilization
efficiency is currently the main measure¾ Adopt large scale, high parameters and high efficiency
USC unites to improve the efficiency and reduce the coalconsumption¾ The every single 1% increase of efficiency can reduce
2~3% CO2 emission
Fuel alternation -- limited by natural gas resources¾ Adopt NGCC (lower CO2 emission per unit power
generation quantity)
Research and develop CO2 separation and storage technology,
the primary measure in the future

44

CCS—Carbon Capture and Storage

Separation and capture: separate and capture CO2 fromflue gasTransportation: Transport captured CO2 to the proper
storage site which may have distance from the emission
sources

Geological storage: another potential CCS technology is
to inject the captured CO2 into geological structures,deep ocean, or solidified it in inorganic carbonate
45
through industry process

Three Main Methods to Capture CO2 in Thermal Power Plant

5－15％CO2

20－40％CO2>90 ％CO2

46

Thank You!
20072007-1010-23

47

Day 1 Monday 15 October 2007
Session 2: Clean Coal Power Generation

Speech 2 US
The Role of Technology in Mitigating Global Climate Change

Mr. Frank Princiotta
Director
Air Pollution Prevention and Control Division
Environmental Protection Agency (EPA)USThe Role of Power Generation Technology in Mitigating Global Climate Change
By Frank Princiotta
Director, Air Pollution Prevention and Control Division
National Risk Management Research Laboratory
Office of Research and Development
US Environmental Protection Agency
Abstract
Anthropogenic emissions of greenhouse gases, especially carbon dioxide, CO2, have led to increasing
atmospheric concentrations which are mostly responsible for the roughly 0.8 oC. global warming the earth has
experienced since the industrial revolution. With industrial activity and population expected to increase forthe rest of the century, large increases in greenhouse gas emissions are projected, with additional andpotentially substantial subsequent global warming predicted. Using a powerful PC-based global climate model,
global warming is projected for two business as usual cases as well as simple yet instructive scenarios where
major programs are initiated to limit CO2 emissions. The paper provides a brief overview of the forces driving
CO2 emissions, how different CO2 emission trajectories could affect temperature this century, with a focus on
power generation mitigation options, and R&D priorities. While much literature exists on various aspects ofthis subject, this paper aims to provide a succinct integration of our best knowledge of the projected warming
the earth is likely to experience in the decades ahead, the emission reductions that may be needed to constrain
this warming to tolerable levels, and the technologies potentially available to help achieve these emission
reductions.
1. Introduction
In February, 2007 the Intergovernmental Panel on Climate Change (IPCC) (1) concluded that:- “Warming of the climate system is unequivocal, as is now evident from observations of increases in global
average air and ocean temperatures, widespread melting of snow and ice, and rising global average sea level.”- “Most of the observed increase in globally averaged temperatures since the mid-20th century is very
likely due to the observed increase in anthropogenic greenhouse gas concentrations.”-“The combined radiative forcing due to increases in carbon dioxide,… is very likely to have been
unprecedented in more than 10,000 years.”- “The total temperature increase from 1850 – 1899 to 2001 – 2005 is 0.76 oC.”
- Depending on the assumed greenhouse gas emission trajectory, warming in 2095, relative to pre-industrial
levels, is projected to be 1.6 to 6.4 oC
Given these findings, this paper will examine the critical energy sector with the aim of evaluating the abilityof technologies to moderate projected warming. The author will discuss the factors that lead to increasing
emissions of CO2, the critical greenhouse gas, and the anticipated importance of key countries. Then, CO2 emissions
will be projected into the future for key sectors. The author will summarize the state of the art of technologies andR&D priorities for the key power generation sector. Finally the adequacy of research, development, demonstrationand deployment will be discussed. (Note that in this paper, all CO2 concentrations will be in ppmv and all warming
will be realized or transient warming, unless specifically identified, as opposed to equilibrium, also known as
eventual warming.)
Although, the scope of this paper is limited to a consideration of power generation technologies that canplay a significant role in reducing CO2 emissions, it is important to note that availability of such technologies will
be necessary but not sufficient to constrain emissions. Since many of these technologies have higher costs and/or
greater operational uncertainties than currently available carbon intensive technologies, robust policies will need
to be in place to encourage their utilization.
2. Factors That Drive Emissions of CO2
The World Resources Institute (2) has examined the factors that have driven CO2 emissions for key
countries in the 1992 to 2002 time period. The factors considered are: Gross Domestic Product (GDP), growth
per capita, population growth, carbon intensity growth per unit of energy (more coal in the mix increases this factor),and the growth of energy usage per unit of GDP. The sum of these factors approximates the annual CO2 growthrate. The author has used the Institute’s data to generate Figure 1, which shows how these factors haveinfluenced the annual growth rate of CO2 for selected countries during this ten-year period. As can be seen for
the world, despite decreases in the energy use per unit of GDP, the CO2 growth rate has been about 1.4% per
year. The rate for the U.S. also has been about 1.4%, but the growth rate for China and India has been about 4%
per year driven by economic growth, and for India, population growth as well. Note that in the absence ofsignificant decreases in energy use per unit of economic output, CO2 emission growth rates would have been
substantially greater.

Figure 1. Factors driving atmospheric concentrations of CO2 for selected countries
However, a recent analysis by Raupach (3) concluded that in the period 2000 to 2004, CO2
worldwide emissions have increased more rapidly than in previous years and more rapidly than predicted; atan annual growth rate of 3.2%. This is more than twice the growth rate of the1992 to 2002 period. Rapidly
developing economies in China and other Asian countries are particularly significant in this recent andtroubling trend. China is currently constructing the equivalent of two, 500 megawatt, coal-fired power
plants per week and a capacity comparable to the entire United Kingdom power grid, each year (4).. Figure
2 summarizes these global emission trends, including the recent 2000 to 2004 data.

2

Figure 2. Most Recent CO2 Emission Data by Countries and Sectors(Note that the following regional designations: FSU=republics of the former Soviet Union,
D1=15 other developed nations, including Australia, Canada, S. Korea and Taiwan, D2=102
actively developing countries, from Albania to Zimbabwe and D3= 52 least developed
countries, from Afghanistan to Zambia.)

4. What Levels of Warming are Projected, What Are the Uncertainties?
A credible base case, or business as usual scenario, must be established if we are to estimate warmingwith any confidence between now and the year 2100. IPCC (1), IEA (5), and Hawksworth (6) have all
postulated such scenarios that allow such estimates. The IEA base scenario was selected as the basis for thisanalysis, since it consistent with current driving forces and does not assume major technology changes overtime. Since it was limited to 2050, the author extended it to 2100 by assuming reduced emission growth rates
between 2050 and 2100. It assumes the following CO2 growth rates in the specified time intervals: 2000 to
2030, 1.6%; 2030 to 2050, 2.2% (from IEA); 2050 to 2075, 1.2%; and 2075 to 2100, 0.7%. Note that the
reduced 2050 to 2100 growth rate assumption, was based on projected declines in population growth rates, but
relatively stable GDP, carbon intensity and energy intensity growth rates.
Figures 3 and 4 present model-generated graphics of both CO2 concentrations and warming frompre-industrial times projected to 2100 assuming this emission scenario. The MAGICC (version 4.1) model(Wigley (7)) was used. An earlier version of this PC- based model was used by the IPCC in its Third
Assessment Report (TAR) to evaluate impact of various emission scenarios. MAGICC is a set of coupled gascycle, climate, and ice-melt models that allows the determination of the global-mean temperature resulting
from user-specified emissions scenarios, which the author generated. Note that in both figures, the uncertainty
range is included. As can be seen, warming uncertainties are much higher than for concentration projections.
Also note, warming is projected to continue after 2100. When one accounts for the continued
warming projected into the next century, the equilibrium or eventual warming is projected to range from 3.0
to 8.1 oC with the best guess at 4.8 oC above 1990 levels; this assumes an ultimate steady 1000 ppm CO2
concentration.
The main uncertainty factor for warming projections, is the extent to which the atmosphere issensitive to a doubling of CO2 concentration, i.e., how much does the global equilibrium temperature changewith such a doubling. IPCC (1), Wigley (7), and others state that this is quite uncertain, and their estimates
range from 1.5 oC to 4.5 oC.

3Figure 3. Projected CO2 concentrations for Base Case

Figure 4. Projected Warming for Base Case
5. What Levels of Mitigation Are Achievable
Figure 5 presents the recent (April 2007) IPCC (8) analysis relating projected warming from1990 to
2100, to the following global impacts: fresh water availability, ecosystem damage, food supplies, seawater rise,
extreme weather events and human health impacts. The author has added projected warming ranges for a credible
business as usual case and an aggressive global mitigation case. It is significant that current (2007) warming (0.3oC since 1990 and 0.8 oC since 1750) has already had measurable impacts.
Base case warming in 2100 (from 1990) is projected to be from 2.2 to 4.7 oC degree (3.2 oC the best
guess), yielding potentially severe impacts, especially in the middle and upper end of this uncertainty range.
Particularly troublesome impacts include: millions of people under water scarcity stress, wide scale ecosystem4extinctions, lower food production in many areas, loss of wetlands, damage and mortality from storms and floods,
and increased health impacts from infectious diseases.
It is important to note that when one accounts for current emission trends, the current unavailabilityof low emitting technologies and the likelihood of inaction in the near term, limiting warming to 2.0 oC(range of 1.3 to 2.8 oC) is likely the best result achievable even with a major global mitigation program (e.g.,decreasing CO2 emissions 1% per year starting in 2010). Figure 6 indicates global impacts will besignificant, even assuming such an aggressive mitigation case.
Therefore, for this analysis, emission scenarios were evaluated to see what reduction levels, startingin what year, would limit warming below about 2.0 oC degree. Figures 6 and 7 depict results of a large
number of MAGICC cases, indicating annual emission reductions required to meet this warming goal, alongwith corresponding CO2 concentration estimates. Note that an annual decrease of 0.00% means emissions
are held constant, at the start year.

Figure 5. Projected global warming impacts as a function of 2100 warming from 1990, degree oC.
Impact starts at beginning of narrative and dotted arrows indicate impacts increase with increasing warming.

5

Figure 6. Best guess 2100 warming as function of annual emission decrease rate and year reductions start

Figure 7. CO2 ppm in 2100 as a function of annual emissions decrease rate and year reductions start
As can be seen, major annual decreases in emissions will be necessary if a warming target below
2.0 oC is to be achieved. Note that the earlier this reduction starts, the less the annual reduction rate has tobe, to meet a given warming target. For example, if such a program were to start in 2015, reductions
would need to be about 1% annually to limit warming to about 2.0 oC from 1990; whereas if such a
program were to start in 2025, annual reductions would need to be about 1.8 %. Again, it must be notedthat there is a large range of uncertainty in the resulting temperature for a given maximum CO2
concentration. Figure 8 illustrates this, by displaying the range of projected warming, from 1990, for aparticular emission scenario, i.e., an annual decrease of 1%, starting in 2010, projected to constrain
concentrations to the 440 to 480 ppm range. Note that the high end of this range is higher than the low endof the business-as-usual case (Figure 4). This highlights the magnitude of the uncertainties in our current
models, of which MAGICC is representative.
6

Figure 8. Projected warming range for a 1% annual decrease in CO2 emissions started in 2010
Figure 9 illustrates the major challenge such reductions represent, relative to our base case emission
trends. The base case emission trajectory is compared to a mitigation scenario where emissions are decreasing
at a rate of 1 % per year starting in 2010. This would limit concentration to 460 ppm and warming to 1.9 oC
above 1990 levels.

Figure 9. Base case & scenario to limit CO2 to <2 C in 2100; units: Gt Carbon (note: 3.67 Gt CO2 per Gt C)
Note that the area between the curves represents the amount of carbon avoidance needed to achieve
the target temperature versus the base case: over one trillion tons of carbon or over 3.7 trillion tons of CO2
over the 90-year period. This represents what can only be described as a monumental political, social, andtechnological challenge.
6. The Mitigation Challenge; Which Sectors are Most Important
In order to identify the most productive mitigation strategies, it is necessary to understand the current
and projected sources of CO2 and the other greenhouse gases. The author has derived the information in
Figure 10 from IEA (6). The upper graphic projects world CO2 emissions by sector. It suggests that power
generation and transportation sources are the fastest growing sectors and will be the key to any successful
mitigation strategy. There is historical evidence that as a country develops economically, it uses greater
quantities of electrical power and experiences a sharp growth in the number and use of motor vehicles andother transportation sources. China and India, with a cumulative population of over 2.4 billion, are projected7

to continue their rapid economic expansion with commensurate pressure on the power generation andtransportation sectors.

Figure 10. Base case , ACT MAP Control Scenario and CO2 Emissions Avoided per IEA ( )7. The Mitigation Challenge; What role can energy technology play and what are the options?
At the request of G-8 Leaders & Energy Ministers in 2005, in order to understand the potential ofvarious energy technologies to avoid CO2 emissions, IEA (5) evaluated what it called Accelerated Technology(ACT) scenarios. Of these, the ACT Map scenario is the most optimistic, assuming an aggressive andsuccessful R, D & D program to develop and improve technologies and a comprehensive technology
demonstration and deployment program. It also assumes policies in place that would encourage the use of
these technologies in an accelerated time frame. These include CO2 reduction incentives to encourage lowcarbon technologies with costs up to $25/metric ton CO2 in all countries from 2030 to 2050. The incentives
could take the form of regulation, pricing, tax breaks, voluntary programs, subsidies, or trading schemes.
The middle graphic of Figure 10 projects CO2 emissions by sector, for the ACT Map scenario, basedon their assumption that major technology implementation starts in 2030. The bottom graphic depicts the CO2
savings projected by sector using the ACT Map scenario. Most of the savings relate to the power generation
sector, which includes both production and end use savings. Note that savings attributed to the transportation
sector include the savings associated with transforming less coal, petroleum, and natural gas to liquid fuels
and their associated CO2 emissions. This IEA scenario is projected to result in the mitigation of 32.5 Gt of
CO2 in 2050. As will be discussed subsequently, this level of mitigation, would be impossible without the useof improved and in some cases breakthrough energy technologies. Such technologies are necessary for both
energy production, i.e., power generation, and to enhance end use efficiency, i.e., lower emission vehicles.
It is important to note that for the IEA Map scenario extended to 2100, MAGICC calculations
indicate best-guess CO2 concentrations in 2100 of 500 ppm and corresponding warming of 2.1 oC relative8

to1990. This is despite the IEA assumption of an aggressive R,D&D and deployment program and the author
optimistically assuming further major (2% per year) emission reductions for 50 years beyond the IEA timeframe of 2050. This suggests that even a major global mitigation program, based on successful development
and deployment of several new technologies, will still allow substantial global warming by 2100.
Let us now focus on the critical power sector, and examine the technology options available, theircurrent state of the art, and the required R, D&D for them to meet their potential to avoid CO2 emissions.
8. Power Generation Sector
Of all the sectors, the power generation sector, which is projected to grow at an annual rate of 2%,
has the greatest potential to reduce CO2 emissions in the coming decades. However, it should be noted that
there are major capacity expansions underway for coal-fired power generation in China, India, and othercountries. Since such plants have no CO2 mitigation technology planned and can have lifetimes up to 50 years,
the sooner technology is ready for implementation and mandated, the sooner new plants can incorporate suchtechnology and control emissions. Current retrofit technology is theoretically available, but will likely besubstantially more expensive per unit of power generated, than would be the case for new plants with CO2
capture built in or advanced CO2 removal retrofit technology now in the early development stages.
Major reductions can result from lower emissions on the generation side and as a result of lower
usage via enhanced end use efficiency on the user side. Table 1 presents a summary of major generation
options that offer significant opportunities for CO2 mitigation. They are presented in the order of highest
potential for CO2 mitigation consistent with the IEA ACT Map scenario. Included in this and the subsequent
tables are the IEA projected CO2 savings for each technology in Gt of CO2 in 2050. To put these numbers inperspective, to achieve the mitigation depicted in Figure 9, total required savings in 2050 is about 40 Gt CO2(10.9 Gt C) and for the less aggressive IEA Map scenario, 32Gt of mitigation would be accomplished .
Key generation technologies include nuclear power, natural gas/combined cycle, and three coal
combustion technologies (IGCC, pulverized coal/oxygen combustion, and conventional pulverized coal), allwith integrated CO2 capture and underground storage. The three coal capture technologies are quite important;
the IEA scenario projects each of the three to avoid 1.3 Gt of CO2 in 2050. Figure 11 illustrates the major
components of each technology. IGCC technology is the primary focus of the U.S. R,D&D program, but
requires complex chemical processing, pure oxygen for the gasification process and can not be readily
retrofitted to existing plants. Oxy-combustion systems also require pure oxygen for combustion but are lesscomplex and have the potential for retrofitting existing plants. CO2 removal via scrubbing, adsorption or
membrane separation is conceptually simple, is inherently retrofitable, but is at an early development stage;commercial amine scrubbers use large quantities of energy for sorbent regeneration and are expensive. MIT(4) recently completed an in-depth study of coal in a carbon constrained world and concluded that: “… CO2
capture and sequestration is the critical enabling technology that would reduce CO2 emissions significantly
while also allowing coal to meet the world’s pressing energy needs.” They concluded that current researchfunding is inadequate and “what is needed is to demonstrate an integrated system of capture, transportationand storage of CO2, at scale.”With the exception of wind power, renewable technologies (green font in Table 1) are not projected tohave major mitigation impacts in the 2050 time frame. In the case of solar generation, the technology is
projected to be prohibitively expensive unless there is a major research breakthrough. For biomass, major
utilization is projected to be limited by its dispersed nature, its low energy density, and competition for thelimited resource in the transportation sector.
The author rates R,D&D needs in the power generation sector critical, especially in the area of CO2
capture and storage (CCS) and for the next generation of nuclear power plants. All three capture technologies
described above, warrant aggressive R,D,D & D programs. The author concurs with MIT (4) that there are too
many uncertainties with regard to IGCC to limit R,D&D focus to that technology alone. Therefore much moreemphasis should be placed on pulverized coal/oxygen (oxy-fuel) combustion, and high efficiency pulverizedcoal with CO2 flue gas capture technology. Underground sequestration will be needed for each of thesetechnologies and is in an early developmental stage, with extraordinary potential. However, there are a host ofquestions that can only be resolved through a major program with a particular focus on demonstrations for the
key geological formations, most applicable to the greatest potential capacity. MIT (4) estimates that 3 full9

scale CCS projects in the U.S. and ten worldwide are needed, to cover the range of likely accessible geologies
for large scale storage.
For advanced nuclear power, the technology is quite promising and could start making a major
impact by 2030. However, the technology needs a number of successful demonstrations to allow for
resolution of remaining technical problems and to instill confidence in the utility industry that the technology
is affordable and reliable, and to the public, that it is safe.
Figure 12 summarizes the IEA projection for the impact of key technologies in avoiding CO2
emissions in the power generation sector in 2050. As can be seen, assuming an aggressive R,D&D andincentive programs, end use efficiency improvements, carbon capture and sequestration and nuclear power are
projected to play an important role in that time frame.
Table 1. Candidate Technologies for CO2 Mitigation From Power Generation (projected impact in Gt/year of CO2)
Technology

Current State of the Art

2050
ImpactIssuesR,D&D Needs

Other Potential Environmental
Impacts

Nuclear Power-next
generation

Developmental, Generation III+and IV: e.g. Pebble Bed Modular
Reactor and Supercritical Water
Cooled Reactor

1.9

Deployment targeted by 2030 with afocus on lower cost, minimal waste,enhanced safety and resistance toproliferation

High, Demonstrations of key
technologies with complimentaryresearch on important issues

Reduction in emissions of SOx, NOx,Fine PM; small but potent and longlived waste, could contaminate small
area

Nuclear Power-current
generation

Commercial, Pressurized Water
Reactors and Boiling Water
Reactors (Generation III)

1.8

Medium, Waste disposal research

Reduction in emissions of SOx, NOx,Fine PM; small but potent and longlived waste, could contaminate smallarea

Natural Gas Combined
Cycle

Commercial, 60% efficiency

1.6

Plant siting, high capital costs,
levelized cost 10 to 40% higher thancoal or gas plants, potential U
shortages, safety, waste disposal andproliferation
Limited by natural gas availability,
which is major constraint; highefficiency & low capital costs

Medium, higher efficiencies with newmaterials desirable

Reduction in emissions of SOx, NOx,Fine PM; fewer mining impacts andResidues for disposal or use

Wind Power (renewable)

Commercial

1.3

Costs very dependent on strength ofwind source, large turbines visually
obtrusive, intermittent power source

Medium, higher efficiencies, on-shore
demonstrations

Reduction in emissions of SOx, NOx,Fine PM; fewer mining impacts andResidues for disposal or use; extraction
R&D could enhance availability of CH4

Coal IGCC with CO2
Capture and Storage

IGCC : early commercialization ,Underground storage (US) : early
development.

1.3

Lower power plant efficiency yields
IGCC :High capital costs, questionable High, IGCC : Demos on a variety offor low rank coals, complexity andgreater emissions of SOx, NOx, Finecoals, hot gas cleanup research; US :potential reliability concerns; US : Cost, major program with long term demos
PM and coal mining impacts
safety, efficacy
evaluating large number of geologicalformations to evaluate efficacy, cost andsafetyPulverized Coal/Oxygen
combustion with CO2
Capture and Storage

Developmental

1.3

Lower power plant efficiency yields
Oxygen combustion allows lower cost High, large pilot followed by full scale
CO2 scrubbing, but oxygen production demos needed, low cost O2 production greater emissions of SOx, NOx, Finecost is high; US : Cost, safety andneeded, US requires major program (see PM and coal mining impacts
permanency
write-up above)

Pulverized Coal with CO2 Underground storage
developmental; CO2 scrubbing
Capture and Storage
with MEA near commercial but
too expensive

1.3

US : Cost, safety and efficacy issues,
CO2 scrubbing energy intensive:
yielding unacceptable costs

First generation commercial, but
Solar-Photovoltaic andconcentrating (renewable) very high costs

0.5

Costs unacceptably high, solar
High, breakthrough R,D&D needed toresource intermittent in many locations develop & demo cells with higher
efficiency and lower capital costs

Reduction in emissions of SOx, NOx,Fine PM; fewer mining impacts andResidues for disposal or use

0.5

Biomass dispersed source, limited to
20% when co-fired with coalHydroelectric (renewable) Commercial

0.5

Capital costs high, potential ecological Medium, minimize environmental
disruption, siting challenges
footprint

Reduction in emissions of SOx, NOx,Fine PM; fewer mining impacts andResidues for disposal or use; however
potential eco impacts from biomass
plantations
Ecosystem Impacts

More Efficient Coal Fired Early commercialization ofsupercritical and ultra
Power Plants
supercritical

0.2

Currently maximum efficiency of 45%,
yielding 36% less CO2 than current
fleetHigh, new affordable materials needed
to enhance efficiency to 50 to 55%

Small reduction in emissions of SOx,
NOx, Fine PM; fewer mining impacts
and Residues for disposal or use

0.2

IGCC: High capital costs, complexity
and reliability concerns, only modest
CO2 savings without CCS

High, Demos on a variety of coals, hot
gas cleanup research

Small reduction in emissions of SOx,
NOx, Fine PM; fewer mining impacts
and Residues for disposal or use

Biomass as fuel and cofired with coal(renewable)

Coal IGCC with no CO2
Capture and Storage

Commercial, steam cycles

IGCC: early commercialization

High, US requires major program (see Lower power plant efficiency yields
write-up above); affordable CO2 removal greater emissions of SOx, NOx, Fine
technologies need to be developed and PM and coal mining impacts
demonstrated

Medium, biomass/IGCC would enhance
efficiency and CO2 benefit; also genetic
engineering to enhance biomass
plantations

10

Post
Combustion CO2
Scrubbing

Coal------------------IGCC:
Pre-combustion
CO2 removal

Coal-------------------Coal

Oxy-Fuel(Coal/oxygen)
Combustion

Figure 11. Three key technologies capturing CO2 from coal-fired power plants

Figure 12. For ACT Map scenario, projected CO2 savings in power generation sector by technology
1112. Adequacy of R, D,&D
IEA (5), Hawksworth (6), Morgan (9), MIT (4), and the author nine years ago (Princiotta, (10)), haveobserved that R,D&D funding in the energy area will need to be substantially increased in order for key
technologies to be ready to reduce carbon dioxide emissions in a time frame consistent with constraining
atmospheric concentrations to protective levels. As illustrated earlier, the later a mitigation program is initiated, themore severe emission cuts will need to be if CO2 concentrations above 450 to 500 ppm are to be avoided. Most
recently, The Stern Report (11) concluded: “…support for energy R&D should at least double, and support for the
deployment of new low-carbon technologies should increase up to five-fold.”
Figure 13, generated from IEA data, (12), depicts world research expenditures in critical energy
technology areas, showing the same funding trend. It is also noteworthy that Europe and Japan have beenmuch more active in the nuclear research area, whereas the U.S. is the key player in coal-related research.
It should be recognized that in the last few years, the U.S. has redirected some of its limited researchresources to some key technologies, especially: hydrogen/fuel cells, IGCC, carbon capture and storage, and mostrecently biomass to ethanol technologies. The U.S. has coordinated its efforts in this area through the Climate
Change Technology Program, CCTP (13). Within the constraint of current budget priorities, the CCTP has
coordinated a diversified portfolio of advanced technology R&D, focusing on: energy-efficiency enhancements;
low-GHG-emission energy supply technologies; carbon capture, storage, and sequestration methods; andtechnologies to reduce emissions of non-CO2 gases. Also, the USEPA (14) is implementing a series of voluntary
programs which encourage greenhouse gas reduction. They include: Energy Star for the building sector,
transportation programs and non-CO2 emission reduction programs in collaboration with industry. These programs
could provide a foundation for an expanded program, consistent with the mitigation challenge.
It is important to note most of the non-coal technologies, offer the potential for lower air emissions,water effluents and waste generation residues. IGCC also offers the potential for such benefits; however
incorporating CO2 capture, transport and storage substantially decreases overall plant efficiency, with thepotential for commensurate increases in coal related pollution per unit of power generated. Also, note that thetransportation technologies all offer the potential for reducing our dependency on foreign oil. Further, thecountry or countries that can bring these technologies to market first, have the potential for major revenue
streams, from what could be a huge international market.
mil USD, 2004 prices and exchange rates

25,000Other

20,000Power & S torage
technologies
Nuclear F usion

15,000

Nuclear F ission
10,000

Renewable
EnergyFossil Fuels

5,000

Conservation
1974

1979

1984

1989

1994

1999

2004

Figure 13. World R,D,&D expenditures for key energy sectors, 2004 $ millions

13. Summary and Conclusions-Concentrations of CO2 have increased to 383 ppm from a pre-industrial value of 278 ppm. This increase isdue to anthropogenic emissions of CO2 that can remain in the atmosphere more than 100 years. There is close
to a scientific consensus that much if not all of the 0.8 oC global warming seen since the pre-industrial era
is a result of increased concentrations of CO2 and other greenhouse gases.
12

-Global emissions of carbon dioxide have been accelerating at a rate of about 1.4% per year in the 1992
to 2002 time period. However, recent data suggests an acceleration of emission growth in recent years;
3.2% in the 2000 to 2004 period. China‘s major expansion of its coal-fired power generation capacity, hasbeen a major factor in this unexpected spurt in growth rate.
- Projections of greenhouse warming have been made on a business-as-usual case or base case. This base caseassumes a global annual growth rate of 1.6% in the next 25 years. Under this assumption, CO2 concentration
is projected to increase to 500 ppm in 2050 and 825 ppm by 2100. This will yield a best-guess averagewarming, relative to 1990, of 1.4 oC in 2050 and 3.2 oC in 2100. There is still a large range of uncertainty
associated with these warming projections; the potential warming in 2100 could be as high as 4.6 oC or as low
as 2.1 oC. This warming would be in addition to the 0.5 oC already experienced from pre 1700 to1990.
Warming would continue into next century and beyond, with equilibrium temperatures in the 3.0 to 8.1 oC
range, with the best guess at 4.8 oC. above 1990 levels; this assumes level CO2 concentrations at 1000 ppm.
-If current worldwide emission trends continue to surprise the prognosticators, and grow at 3% per year forthe next 25 years, projected warming would be substantially higher. This scenario will yield a best-guessaverage warming, relative to 1990, of 1.7 oC in 2050 and 4.0 oC in 2100. The potential warming in 2100
could be as high as 5.5 oC or as low as 2.6 oC. Warming would continue into next century, with equilibrium
temperatures in the 3.4 to 9.0 oC range, with the best guess at 5.4 oC.
-It is too late to prevent substantial additional warming, the most that can be achieved would be tomoderate the projected warming. The best result that appears achievable, would be to constrain warmingfrom 1990 to about 2 oC ( between 1.2 and 2.8 oC) by 2100. Figure 6 illustrates that global impacts, even forthis constrained warming scenario, are potentially serious. This suggests that the world community may haveno remaining alternative other than to pursue adaptation approaches aggressively.
-In order to limit warming to 2 oC level, it will be necessary for the world community to decrease annual
emissions at a rate of between 1 and 2% per year for the rest of the century. The earlier the mitigation
program starts, the less drastic the annual reductions would need to be. Since the base case assumes a roughly
1.5% positive growth rate, approximately one trillion tons of carbon (3.7 trillion tons of CO2) will have to be
mitigated by 2100 relative to the base case. This would be a monumental challenge.
-Recent publications were used to relate the implications of a 1 trillion-ton mitigation program to the key
energy sectors and the technologies within those sectors that can contribute to such a major mitigation
challenge. The key energy sectors are power generation, transportation, industrial production, and buildings.
The power sector and transportation sectors are particularly important, since they are projected to
grow at relatively high rates, with China and India being key drivers.
-The power generation sector, projected to grow from a large base at 2% annually, offers the greatest
opportunity for CO2 reductions. However, since the key source of emissions for this sector is coal combustion,
it is critically important to develop affordable CO2 mitigation technologies for such sources and to develop
economical alternatives to coal-based power generation. CCS offer the potential to allow coal use while at thesame time mitigating CO2 emissions. The three major candidates for affordable CO2 capture are: PC boilers
with advanced CO2 scrubbing, IGCC with carbon capture and oxy-fuel combustors. Of the three, only IGCC
is being funded at levels approaching those needed. However, all three approaches rely on underground
sequestration, an unproven technology at the scale required for coal-fired boilers, with many serious cost,
efficacy, and safety issues. Nuclear power plants, natural gas/combined cycle plants, and wind turbines all
have the potential to decrease dependence on coal generation and make significant contributions to CO2
avoidance. An accelerated R, D and D program is particularly important for advanced nuclear reactors, given
their high mitigation potential, yet serious safety, proliferation and waste disposal concerns.

13

-If mitigation of three trillion tons of CO2 is deemed a serious goal, a major increase in R&D resources will
be needed. Technology research, development, and demonstration are of particular importance for coal
generation technologies: IGCC, oxygen coal combustion, and CO2 capture technology for pulverized coal
combustors. All of these technologies will have to be integrated with underground storage, a potentiallybreakthrough technology, but one which is an early stage of development. Also important are next generation
nuclear power plants.
-Given the monumental challenge and uncertainties associated with a major mitigation program, the author
believes it prudent to consider all available and emerging technologies. This suggests that fundamental
research on energy technologies in addition to those in Table 1, be part of the global research portfolio,
since breakthroughs on today’s embryonic technologies could yield tomorrow’s alternatives.
- Finally, availability of key technologies will be necessary but not sufficient to limit CO2 emissions. Sincemany of these technologies have higher costs and/or greater operational uncertainties than currently available
carbon intensive technologies, robust regulatory/incentive programs will be necessary to encourage their utilization.

References(1) IPCC (2007), Climate Change 2007: The Physical Science Basis, Summary for Policymakers, Fourth
Assessment Report of the Intergovernmental Panel on Climate Change, http:www.ipcc.ch/spm2feb07.pdf(2)World Resources Institute (2006): Climate Analysis Indicators Tool (CAIT) on-line database version 3.0.,
Washington, DC: World Resources Institute, available at: http://cait.wri.org(3) Raupach, M.R., et al., Global and regional drivers of accelerating CO2 emissions, Proceedings of the National
Academy of Sciences, May 22, 2007
(4) MIT, The Future of Coal, An Interdisciplinary MIT Study, 2007
(5) International Energy Agency, Energy Technology Perspectives 2006, OECD-IEA, 2006
(6) Hawksworth, J., The World in 2050; Implications of global growth for carbon emissions and climate change
policy, PriceWaterhouseCoopers, September 2006
(7) Wigley, T.M.L. and Raper, S.C.B.; Interpretation of high projections for global-mean warming. Science 293, 451–
454.MAGICC (Model for the Assessment of Greenhouse gas Induced Climate Change) can be downloaded at
http://www.cgd.ucar.edu/cas/wigley/magicc/index.htm, 2001

(8) IPCC (2007), Climate Change 2007: Impacts, Adaptation and Vulnerability, Summary for Policymakers,
Fourth Assessment Report of the Intergovernmental Panel on Climate Change,
http://www.ipcc.ch/SPM13apr07.pdf(9) Morgan, G., Apt, J., Lave L., The U.S, Electric Power Sector and Climate Change Mitigation, Pew Center:
Global Climate Change, June 2005(10) Princiotta, F.T., Renewable technologies and their role in mitigating greenhouse gas warming,. Elsevier
Science Publishers, US-Dutch symposium: Facing the air pollution agenda for the 21st century, vol. 72, 1998(11) Stern, N, The Economics of Climate Change, The Stern Review, 2006 pre-publication version: website:
http://www.hm-treasury.gov.uk/independent_reviews/stern_review_economics_climate_change/stern_review_report.cfm(12) International Energy Agency, RD&DBudgets, website: http://www.iea.org/RDD/TableViewer/(13) CCTP, Climate Change Technology Program, website: http://www.climatetechnology.gov/.
(14) USEPA, Current and Near Term Greenhouse gas Reduction Initiative, website:www.epa.gov/climatechange/policy/neartermghgreduction.html

14

Global Climate Change;
The Technology ChallengeFrank Princiotta,
Director Air Pollution Prevention and Control Division“Harmonious and Sustainable Coal Power Generation”
APEC Clean Fossil Energy Seminar

October 15, 2007

Office of Research and Development
National Risk Management Research Laboratory

Presentation Objectives• What is a credible warming scenario given current andprojected emission trends? What factors and sectors drive
emissions?
• What level of emission reductions will constrain warming

to acceptable levels? What technologies will be needed toconstrain warming to acceptable levels?
• Are such technologies available and if not is R,D,D&D

adequate?

1Annual Growth Rate, %Factors Driving CO2 Annual Growth (1992-2002)

2

Most Recent CO2 Emission Databy Countries and Sectors

3

FSU=republics of the former Soviet Union,
D1=15 other developed nations, including Australia, Canada, S. Korea and Taiwan,
D2=102 actively developing countries, from Albania to Zimbabwe andD3= 52 least developed countries, from Afghanistan to Zambia.

Two Emission Scenarios: IEA base: Original assumed growth rate from2000 to 2030 of 1.6%; Revised growth rate from 2000 to 2030 of 3.0%

CO2 Emissions,
Gt C per YearCO2 ppm

Warming from1990, C degree

4

2000

2050

2100

Estimated Warming in 2100 for Emission Control Scenarios
Warming from Pre-Industrial to 2100

Impact of CO2 Control, from Pre-Industrial to 2100 on Global Warming (degree C)
Base Case: IEA 2006

4

3.5
2010
2015

3

2025
2.5

2
Base

0.00%

0.50%

1.00%

1.50%

2.00%

Annual Decrease in CO2 Emissions Needed5Two Mitigation Scenarios: Original assumed emission 2000 to 2025
growth rate of 1.6%, then a 1% annual reduction; Revised 2000 to
2025 growth rate of 3.0%, then an annual 1% reduction

CO2 Emissions, Gt
C per YearCO2 ppm

Warming from1990, C degree

6

2000

2050

2100

Global Impacts vs.1990 to 2100 Warming per IPCC, 2007
2007 warming-------------IEA Business as usual range------------

7---Major mitigation program---IEA Accelerated Technology (ACT) Scenarios• Mandate by G-8 Leaders and Energy Ministers• Assumes aggressive R,D&D Program• Major mitigation starts in 2030
• Assumes policies in place to encourage technology

use in accelerated time frame– CO2 reduction incentives of up to $25 per ton– Policies include regulation, tax breaks, subsidies
and trading schemes
Reference: International Energy Agency, Energy Technology
Perspectives 2006, OECD-IEA, 2006
8

60
50

Business as Usual,
versus ACT Map
Control Scenario, IEA
2006

Gt CO2 per Year

40

World Projectionof CO2 Emissions 30
by Sector (IEA,
20
2006)
10
0
40

IEA Baseline
ACT Map
Scenario

Buildings
Industry
Transport
Energy Transformation
Power Generation

30

20

10

0
2000

35

IEA ACT Map
Scenario, CO2
Reductions by
Sector

30

2010
2005

2020
2015

2030
2025

2040
2035

2050
2045

25
20
15
10
5

9

0
2000

2010

2020

2030

2040

2050

2000 2010 2020 2030 2040 2050
2005 2015 2025 2035 2045

CO2 Emissions for IEA Base Case and ACT Map Scenario

10Projected Warming for IEA Base Case & ACT Map Scenario

11Power Generation Sector• Projected to grow from large base at 2% annually, China and India

critical; offers greatest opportunity for reductions; 38% of US CO2• Coal combustion key source, important to develop CO2 CCStechnologies and alternatives to coal-based systems.
• 3 major candidates for CO2 capture: PC boilers/advanced CO2

scrubbing, IGCC/carbon capture and oxygen-fed combustors/
advanced CO2 scrubbing. Only IGCC funded at significant levels• Underground storage an unproven technology at scale needed forcoal-fired boilers, with serious cost, efficacy, & safety issues.
• Nuclear power plants; accelerated R, D and D program is important

for advanced reactors, given high mitigation potential, yet serious
safety, proliferation and waste disposal concerns.
• Natural gas/combined cycle plants, wind turbines also have
12

potential to decrease dependence on coalCO2 Avoidance in Power Generation Sector for IEA
ACT Map Scenario by Energy Category

13Three Options for CO2 Capture from Coal Power Generation Plants
Post
Combustion CO2
Scrubbing

Coal------------------Coal
IGCC:
Pre-combustion
CO2 removal-------------------Coal

Post Oxy-fuelCombustion CO2
Scrubbing14

Major Increase in R,D,D &D Essential• If mitigation of one trillion tons of carbon is deemed a serious

goal, a major increase in R,D,D&D needed. The Stern Report :“…support for energy R&D should at least double, and support
for the deployment of new low-carbon technologies should
increase up to five-fold.”• Currently world spends $1trillion on military, $10 billion on allenergy technologies, $1.5 billion on coal technologies• Current CO2 mitigation research funding in US and globally

relatively flat in recent years, US spending on mitigation 70%
lower than that in response to oil shortages in mid-1970’s.
• R,D&D particularly important for coal generation technologies:

IGCC, oxy-coal combustion, and CO2 capture technology for PC
boilers; all need to be integrated with underground storage, a key
technology, but need numerous demos
15• Also important; next generation nuclear power plants

Conclusions• Limiting warming to below 2.5 C will be a monumental challenge;

growth rate of 1.5% to 3% must change to -1 to -2%; sooner control
starts, less drastic are controls• Warming of at least 2 C inevitable, adaptation strategies needed• Power production and mobile sources key sectors• Required technology is not available; major advances necessary inunderground storage, PC CO2 capture, IGCC, oxygen combustion,
advanced nuclear, mobile source fuels/propulsion systems andrenewables• No “silver bullets”, all promising technologies should be pursued• Research funding is grossly inadequate; “too few eggs in too few

baskets”• Technology necessary but not sufficient; utilization requires
16

incentives/regulations

Our Stakeholders Count on Us

17

Day 1 Monday 15 October 2007
Session 2: Clean Coal Power Generation

Speech 3 PR China
GreenGen Technology

Mr. Hu Shihai
Assistant President
China Huaneng GroupPR China

Hu Shihai
China Huaneng Group Assistant President•
graduated from Mechanical Engineering Dept. of Shanghai
Jiaotong University•
was Deputy Superintendent of Huaneng Shanghai Shidongkou
No.2 Power Plant, Assistant President and General Manager ofWorkplace Safety Department of Huaneng Power International, Inc.
•
currently is the Assistant President of China Huaneng Group andDirector of the Department of Safety Supervision, Science andTechnology and Environment Protection.

GreenGen Project
Hu Shihai
China Huaneng Group2007.10 Xi’an

Contents• Background• Implementation of GreenGen• Development plan and technical route ofGreenGen• Building IGCC power plant withindependent innovative gasification• Other R&D projects• Conclusion

1. BackgroundChina’s Energy Consumption
mainly based on coal in a long time
1000

Total Capacity
800

Coal-based Capacity
622

GW

600
400

319

200

138
66

0

1980

1990

2000

2006

The installed capacity was excess 620 GW in 2006
In 2006, the proportion of thermal power in the country’s installedcapacity was about 75%, of which coal-based units was about 95%

Power Generation is primary CO2Emission

Power industry is the most important CO2 emission source. It is
about 50％ of the total emission in China, and still increases in futuresource: IEA, World Energy Outlook 2002

Near Zero Emission
Power Plants

USA－ FutureGen

EU－ HypoGen

China－ GreenGen

Japan－ Eagle project

Australia－ ZeroGen

GreenGen flow diagram2. Implementation of GreenGen

GreenGen Ltd., Co.
was founded
Under the support of NDRC,MOST and other ministries
and commissions, CHNG united other 7 energy
enterprises founded the GreenGen Ltd., Co. China .
China Huaneng Group
China Datang Group
China Huadian Corporation
China Guodian Corporation
China Power Investment Corporation
Shenhua GroupState Development & Investment Co.
China Coal GroupThe founder agreement signingceremony of GreenGen Ltd.

Energy enterprises support environment-friendly ,highefficiency ,Independent innovation

Vice-Premier Zeng Peiyan was meeting
principals that attended the GreenGen Ltd.
founder agreement signing ceremony

3. Development plan and technicalroute of GreenGen

Objective of GreenGen• To research/develop and demonstrate (RD&D) the
integrated coal gasification, hydrogen production,hydrogen power generation and CO2 sequestration
system• To achieve high coal-based generation efficiency
and zero emission of all pollutant and CO2• To master the core technologies, sustain
technologies and system integration technology
and form GreenGen technology with Chinese
property right• To conduct commercial demonstration at
acceptable price andrealizesustainable
development of coal-based generation

Three Stages of the GreenGen
Plan
R&D for Key technologies ;Improve IGCC technology

IGCC plant
Improve the IGCC polygeneration(Power-Heat-Syngas) technology

2000 t/d Gasification
250 MW IGCC
polygeneration (PowerHeat-Syngas)

Economic and technical compare
between 3500 t/d and 2×2000 t/d
gasifers
H2 production
CCS
Fuel cell power generation technology

GreenGen demoengineering

Build a 400MW GreenGen
demo-Engineering, including
H2 production, FC power
generation, H2 turbine
combined cycle generation and
CCS
Operate the GreenGen plant
Prove the GreenGen
economic viability

Build the GreenGen
Labaratory

Preliminary work of the GreenGen
demonstration

Prepare and extend forcommercial system

Stage I

Stage II

Stage III

2006-20092010-20122013-2015

GreenGen key technologies

Hydrogen gas
turbine technology
System integration
technology

CO2 capture

Gas cleanup
technology

CO2 storage
technology

Three Stages about ten years

Large high efficiency
gasification technology

Fuel cell power
generation
technology

GreenGen
Demo-power
plant

Near zero
Emission
power plant

Technical diagram for the stage I

Technical flow diagram for thestage II

The main tasks in this Stage: Improve & promote IGCC plant andpolygeneration; Ready for GreenGen demo engineeringTechnical flow diagram for thestage IIIIn this stage to realize the final objective ofGreenGen in about 2015

4. Building IGCC power plant withindependent innovative gasification

IGCC demonstration plant siteTianjin City

Lingang Industrial Park has a number of advantages, including
supplies of coal, water and the availability of land. The
presence of a large number of chemical plants located in the
Industrial Park also creates favorable conditions for the polygeneration system by providing opportunities to utilize thebyproducts and a good direct electricity supply.

IGCC Power Plant -site

The progress of independent
innovative Gasfication technology
Two Stages Gasification
with Dry Feed

700 kg/d 1996

36 t/d (10 MWth ),2004
Funded by MOST in 2005

2000t/d， 2009

GreenGen stage II
signing ceremony on April 18th

CHNG singed the agreement about GreenGen StageII with the government of Tianjin City ,and will build
2×400 MW IGCC in Tianjin

Main equipment biddings
1.AUS
Done
2.GasifierDone
3.Gas turbine Joint bidding
Ongoing• GE+Nanjin Turbine• SIMENS+Shanghai Electric Group• MHI+Dong Fang Electric
4.Others
OngoingThe progress of the project approval
•
•
•

•
•

The IGCC Project has received the 11th five-year plan 863 major
projects support from Ministry of Science and Technology (MOST)
The Project received the Access system application approval fromState grid in Jun. 2007
The Project received Environmental Impact Assessment (EIA) of the
project approval from State Environmental Protection Administration(SEPA) in July 2007
The project has received the all 27 support documents for the
project approval
The project has received the feasible final report approval from
National Electric Power Planning and Design Institute in Aug. 2007

5. The CCS R&D projects

CO2 capture technology
for power plants

Pre-combustion
decarbonisation

OxyfuelPost-combustion CCS• “China-Australia
Announcement for
Climate Chang andEnergy”• Cooperation between
CHNG and CSIRO• 3000～5000t/a PCC
will be build in CHNG
Beijing Thermal Power
Plant, will be
operational by July
2008

GreenGen Co. and TPRI joined the COACH (Cooperation
Action within CCS China-EU ) and will join the cooperation
with UK for CO2 capture and sequestration (NEZC)
GreenGen project will play important role in the both COACH and
NEZC
GeoCapacity

COACH

Geological map of the Bohai and Ordos Basins

CO2 storage indeep geologic
formation andenhance oil recovery

Conclusion•

China’s energy structure requires to develop GreenGen
sustainable development;for•With leadership from NDRC and MOST, we believe the GreenGen
program will be carried out successfully•

Gasification and other technologies of domestic and overseas
enterprises supply the solid fundament of GreenGen program•

The IGCC power plant has been located in Tianjin, and received thenational major project support；the agreement about stage II has
been signed between Tianjing and CHNG, and main equipment
biddings will be finished recently•

The project has received all support documents, the feasible final
report and EIA approval.

•

Besides the GreenGen project, CHNG is researching and developing
the other CO2 capture technologies.

Thank you for your attention
www.chng.com.cn
www.tpri.com.cn
www.greengen.com.cn

Day 1 Monday 15 October 2007

Session 3:
Clean Coal Power Generation

Day 1 Monday 15 October 2007
Session 3: Clean Coal Power Generation

Speech 1 US
How can Environmental Regulations Promote Clean Coal
Technologies in Developing APEC Economies?

Ms. Jette Findsen
Deputy Program Manager
Climate Change
Science Applications International Corporation (SAIC)
USResults of APEC Study:
Environmental Regulations to Promote Clean Coal in
Developing APEC Economies

May XX, 2006

Jette Findsen
Harmonious and Sustainable Coal Power Generation
APEC EGCFE and TPC/CSEE Clean Fossil Energy Seminar
Xi’an, People’s Republic of China
October 15, 2007

Objective and Outline
z Study objective:y Recommend environmental regulations that will encourage clean coalin developing APEC economies that are building new coal-fired
capacityz Presentation outline

y Air emission standards in sample APEC economies
y China, India, Indonesia, Philippines, Thailand, Vietnam
y Developed APEC economies

y Impact of emission standards on clean coal uptake
y Environmental controlsy Advanced combustion technologyy Recommended regulations that will encourage clean coal

One Source, Innovative Solutions

1

China - Air Emission Standardsz Emission standards

combined with levy
system andtechnology
guidelines

y Phase-out of small
power plantsy Policies/guidelines
on installation ofdesulfurizationequipmenty Continuous
emissionsmonitoring (CEMS)
for SO2 in TCZs

2

3

Maximum Emission Levels (mg/m )Time Period

Period I

Period II

Period III(Power Plant Construction Date)(Pre-12/31/96)(1/1/97-1/1/04)(Post-1/1/04)

Date of Implementation

1/1/05

1/1/101/1/05

1/1/101/1/04

Vdaf < 10%

1,500

-

1300

-

1,100

10% ? Vdaf ? 20%

1,100

-

650

-

650

V daf > 20%

1,100

-

650

-

450

650

-

400

-

200

-

-

-

-

150

-

-

-

-

80

1,200

2,100

400

400

Coal FiredNOX

Oil Fired(Boiler)
Oil Fired(Turbine)All

Gas Fired(Turbine)

All
GeneralSO2

Coal/Oil
Fired

2,100

*

*

Approved / Non-TCZ

-

-

1,200

1,200

-

Coal Mine Waste

-

-

-

-

800

Mine Mouth

1,200

Urban Areas

300

200

200

50

50

Rural Areas

600

200

600

50

50

Approved / Non-TCZ

-

-

-

100

100

Coal Mine Waste

-

-

-

200

200

All

200

100

100

50

50

Coal Fired
PM10

Oil Fired

One Source, Innovative Solutions

Indonesia -- Air Emission Standards

Pollutant
1996-2000

Particulate Matter
Sulfur Dioxide
Nitrogen Oxide
OpacityYear
2000 onward

Emission Standard (Mg/m3)
300
1500
1700
Other
40%

150
750
850
20%

z New standards introduced in 2003
z Similar requirements for all units, regardless of fuel typez All units are able to meet the standards

One Source, Innovative Solutions

3

Philippines -- Air Emission Standards
Pollutant
NOx

Plant Type
Fuel Burning Steam Generators:
Existing (< 1993)
New (> 1993)- Coal-fired- Oil-fired

4

Maximum
Permissible Limit (mg/nm3)
1,500
1,000
500

SO2

Fuel Burning Equipment:
Existing (< 1993)
New (> 1993)

1,500
700

PM10

Fuel Burning Equipment:
Urban or Industrialized Area
All other areas

150
200

CO

Any industrial source

500

Mercury as elemental Hg

Any source

5Standards require low-NOx burners and SO2 scrubbers at new plants
z Regulations include an emissions charge proportional to the amount of pollutant emitted
y Industry obtained grace period until necessary controls have been installedz Tax incentives for plants installing or retrofitting pollution control equipmentz

One Source, Innovative Solutions

Thailand – Air Emission Standards
Type and Size of Power Plant

5

Emission Standard
Sulfur Dioxide (ppm)

Oxides of Nitrogen (ppm)

Particulates (mg/m3)

New Power Plant (Permitted after January 31, 1996)
Coal<300 MWe

640

350

120

300-500 MWe

450

350

120

> 500 MWe

320

350

120

<300 MWe

640

180

120

300-500 MWe

450

180

120

> 500 MWe

320

180

120

Natural Gas

20

120

60

Oil

Old Power Plant (Permitted before January 31, 1996)
Coal

700

400

320

Oil

950

200

240

Natural Gas

60

200

60

320

200

120

320

200

120

South Bangkok Thermal

320

180

120

North Bangkok

500

180

150

Unit 1-3

1,300

500

180

Unit 4-13

320

500

180

Existing Power Plant
Bang Pakong Unit 1-4 (Thermal)

Mae Moh

One Source, Innovative Solutions

Vietnam – Air Emission Standards
Plants Permitted in 2006 and Later

6

Fuel Type (mg/nm3)

Parameter
Coal

Oil

Natural Gas

PM10

200

150

50

NOX

650 (coal with VOC content > 10%)1,000 (coal with VOC content ≤ 10%)

600

250

SO2

500

500

300

Individual emission standards are calculated using the following equation:
Cmax = C * Kq * Kv

Sample standards for new individual coal-fired plants,
depending on location (mg/nm3)

Where
C=
Kq = 1
Kq = 0.8
Kq = 0.7
Kv = 0.6
Kv = 0.8
Kv = 1.0
Kv = 1.2
Kv = 1.4

the specific emission limit listed in Table above
if the unit capacity is ≤ 300 MW
if the unit capacity is > 300 MW and ≤ 600 MW
if the unit capacity is > 600 MW
if located < 2km from a natural, cultural, or historic heritagesite (urban area Type I)
if located inside or < 2 km from urban areas Type II, III, and IV,
and outside Type 1
if located inside or < 2 km from an industrial zone or urban
area Type V, and outside Types I, II, III, and IV
if located in a valley
if located in a mountain area

One Source, Innovative Solutions< 2 km from heritagesite (Type 1)

Inside or < 2 km fromindustrial zone or
urban area Type V

Mountain area

300 MW

600 MW

300 MW

600 MW

300 MW

600 MW

PM10

120

84

200

140

280

588

NOX
> 10%
VOC

390

273

650

455

910

637

NOX
≤ 10%
VOC

600

420

1,000

700

1,400

980

SO2

300

210

500

350

700

490

Developed APEC Economies -- Air Emission
Standardsz

7

US: Mix of emissions trading and best available control technology(BACT)/lowest achievable emission rate (LAER) standards
y Emphasis on emissions trading to achieve last incremental reductionsy Trading gives companies flexibility to identify low-cost reductionszzz

Canada: Output-based emission guidelines (kg/MWh)
Australia: Provincial emission limits for NOx and PM
Japan: National NOx emission limits, SO2 limits vary depending on plant size andlocation

Recent New Source Performance Standard (NSPS) and New Source Review (NSR) Requirements for Coal-fired Plants in the US

POLLUTANTNEW SOURCEPERFORMANCESTANDARD (NSPS)RECENT NSR
BACT/LAEREMISSION LIMITRECENT BACT/LAERCONTROLTECHNOLOGYRECENT
BACT/LAERCONTROLEFFICIENCYIN GENERAL(mg/Nm3)

SO2

0.6 to 1.2 lb/106 Btu and
70% to 90%Removal

0.12 to 0.2 lb/106 Btu

Low to Medium Sulfur
Coal, FGD

90 to 95%

new plants built for
<100

NOx

1.6 lb/Megawatt-hourand 0.15 lb/106 Btu

0.05 to 0.1 lb/106 Btu

Selective Catalytic
Technology with LowNOx Burners

50 to 90%

new plants built for
<100

PM10

0.03 lb/106 Btu and 99%
Removal0.01 to 0.015 lb/106
Btu

ESP, Fabric Filter>99.5%

30-50

Opacity

20% Opacity (6 minute
average)a

10% opacity

ESP, Fabric Filter

99.9% TSP--One Source, Innovative Solutions

Mercury Emission Standards for Coal-fired
Powerz Many developing countries have industrial mercury (Hg)emission standards that coal-fired plants can easily meetz Emerging regulations for coal-fired plants in North America
y United Statesy Clean Air Mercury Rule (CAMR) combines cap-and-trade and new source
performance standards for new unitsy Individual states can strengthen cap or set direct permit limits to address
local “hot spots”

y Canaday Provincial caps on Hg emissions from existing coal-fired power plants,
representing 60% national capture in 2010y Capture rates or emission limits for new plants based on BATOne Source, Innovative Solutions

8Regulations on Coal Combustion Wastez Developed APEC economies

y Coal combustion products typically not regulated as hazardous waste
y Regulations cover reporting of quantities and disposal iny Landfills
y Surface impoundmentsy Abandoned or operating minesy Recycled productsz Developing APEC economies

y Most require reporting of quantify produced and disposal methody Few have requirements for disposal methody Some require landfills to be linedy Some incentives for recycling through fee on landfilling

One Source, Innovative Solutions

9

Emerging GHG Regulations Directly Affecting
Coal-fired Power
Emissions Trading
EU Emissions Trading System(EU ETS)- Cap on CO2 emissions from power generation and industrial processes- Entities can purchase emission allowances from other EU ETS installations or GHG
offsets based on CDM/JI projects in other countries- 60% of covered entities have initiated internal abatement

RGGI –US East Coast

Cap on CO2 from power plants starting 2009

US/Canada West Coast

Emerging in Arizona, British Columbia, California, Manitoba, New Mexico, Oregon, Utah,
and Washington

Australia

National cap and CO2 trading for electricity and other sectors by 2012

New South Wales, Australia

Electricity generators must meet average CO2-equivalent emission intensity benchmarks
Tax

Carbon/CO2 tax on fuels

Japan, Norway, Quebec, Sweden, Switzerland
Technology/Fuel Standard

Montana

New coal units must capture and sequester > 50% of CO2 produced

Ontario

Phasing out coal by 2014
Performance Standard

California and Washington

No long-term electricity contracts with generators that emit GHGs in excess of NGCC (or1,100 lbs of CO2/MWh)

Saskatchewan

New facilities must be GHG emissions free or offset emissions

One Source, Innovative Solutions

10

United States -- Technology Results

11

Figure 1. Added and Planned U.S. Coal Fired
Capacity, 1916 - Present
Capacity (MW)

12000010000080000
60000•GHG regulations are driving clean coalin planned capacity

40000
20000
0
1966-75

1976-85

1986-94

Timeperiod
Subcritical

1995Present

PlannedSupercritical and Ultra-supercritical•Regulations have led to adoption ofenvironmental controls•Nearly all new plants use FGDs (90 GW)•100 GW of SCR added between 1994-2005•More efficient combustion technology added inperiods of high fuel prices

Number of Plants

1916-65•Of 159 proposed coal-fired plants innext 30 years, 77 are clean coal
Figure 2. Number and Type of Advanced Coalfired Combustion Technologies Proposed forConstruction in the US Over 30 Years
32
28
28
23
24
20
13
16
12
8
2
4
0
l
FB
C

Sources: Platts. UDI World Electric Power Plants Database,2005 directories. IEA. Coalpower5 Database. 2005

One Source, Innovative Solutions

al
ic
rit
c
r
pe
Su

ca
iti
cr
r
pe
Su
a
ltr
U

n
io
at
c
ifi
as
G

Australia and Japan – Technology Results

12

Figure 4. Added and Planned Japanese Coal
Fired Capacity, 1955 - Present
20000
15000
10000

Recent adoption of supercriticalunits in Australia
z FGDs are minimally deployed
z

5000
0
1955-65

1966-75

1976-85

1986-94

Timeperiod
Subcritical

1995Present

PlannedSupercritical and Ultra-supercritical

High cost of coal and GHG goals
stimulating adoption ofultra/supercritical coal in Japanz All units use FGDs and two-thirds
use SCRs

Figure 5. Added and Planned Australian Coal
Fired Capacity, 1955 - Present
14000

z

Capacity (MW)Capacity (MW)

25000

12000
10000
8000
6000
4000
2000
0
1955-65

Sources: Platts. UDI World Electric Power Plants Database,2005 directories. IEA. Coalpower5 Database. 2005

One Source, Innovative Solutions

1966-75

1976-85

1986-94

Timeperiod
Subcritical

1995Present

Supercritical

Planned

8000
7000
6000
5000
4000
3000
2000
1000
0

Figure 8. Added and Planned Canadian Coal
Fired Capacity, 1955 - Presentz1955-65

1966-75

1976-85 1986-94
Timeperiod
Subcritical

1995Present

PlannedSupercritical

Recent adoption of 450 MW
supercritical unit in Canada
z 76% of capacity has PM
controls
z 20% has SO2 controls

Concerns over energy security
have driven supercriticaltechnology in South Korea

Figure 9. Added and Planned South Korean Coal
Fired Capacity, 1943 - Present

z

60000
Capacity (MW)Capacity (MW)Canada and South Korea – Technology Trends

13

50000
40000
30000
20000
10000
0
1943-65

Sources: Platts. UDI World Electric Power Plants Database,2005 directories. IEA. Coalpower5 Database. 2005

One Source, Innovative Solutions

1966-75
Subcritical

1976-85 1986-94
Timeperiod

1995Present

PlannedSupercritical and Ultra-supercriticalSummary and Implications

14

z Coal waste and water regulations are not strong drivers of environmental

controls or efficient combustiony As standards get higher, cost goes up --> may encourage improved efficiency
z Air emission standards have driven adoption of environmental controls

y Not necessarily more efficient combustion technology
z Resulty Air emissions have decreased
y CO2 emissions have remained the same or increasedz Need regulation of CO2 to encourage more efficient coal combustiony Market-based regulationsy Technology standards
y Efficiency targets
y Performance standard

One Source, Innovative Solutions

Country

Average Efficiency (%)

OECD

36

USA

33-35

China

29-32

India

~30

Environmental Regulations to Encourage Clean
Coal Uptake
z Integrated regulations for air, waste, GHG emissions, andwater importanty CO2 capture does not reduce air emissions by similar amounty Chemicals for preventing air emissions can make ash too toxic forrecyclingy Integration now, avoids cost of retrofitting laterz Regulations that improve efficiency of coal combustion mosteffective at meeting all goals (air, GHGs, waste and water)z Market-based policies ensure the most cost-effective
allocation of resources to meet environmental goalsy However, may “interfere” with national energy security priorities byencouraging switch to low-carbon fuels

One Source, Innovative Solutions

15

Environmental Regulations to Encourage Clean
Coal Uptake (cont’d)z In short term – introduce measure to encourage efficiency

y Harmonize air emission standards for the regiony Develop standards for environmental controls and combustion
technologies
y Track combustion efficiency and set improvement targety Install CEMS for improved monitoringy Run emissions trading pilot for air pollutantsy Strengthen regulations for coal waste and water use
y Switch to performance-based regulation of air pollutantsz In longer term – begin regulating CO2

y Establish price on CO2 and air pollutants through emissions trading or
CO2 performance standard

One Source, Innovative Solutions

16

One Source, Innovative Solutions

Contact Information:
Scott Smouse
Chair, APEC Expert Group on
Clean Fossil Energy
Ph: +1 412 386-5725
Email: scott.smouse@netl.doe.gov
http://www.egcfe.ewg.apec.org/

Jette Findsen
SAIC
Ph: +1 202 488-6624
Email: jette.findsen@saic.com
One Source, Innovative Solutions

17

Day 1 Monday 15 October 2007
Session 3: Clean Coal Power Generation

Speech 2 PR China
Introduction of the First Domestically Manufactured
300-MW CFB Boiler in China

Mr. Jin Yaohua
Deputy Chief Engineer
China Datang Corporation
PR China

金耀华
中国大唐集团公司副总工程师
1982-1996：华北电力科研院
1996-1998：张家口发电厂
1998-1999：秦皇岛发电厂
1999-2003：北京大唐股份公司
2003-至今：中国大唐集团公司Introduction on
the Operation Situation ofFirst Chinese-built
300 MW CFB Boilers

Jin Yaohua
China Datang Corporation

Contents
 Preface General Description of Domestically Applied 300MW CFB Technology
 Experiences and Achievements in Installation & Commissioning Achievements in Stable Running & Environmental Protection Impact
 Experiences and Innovation on Operation & Maintenance Concluding Remarks

1. Preface•••

One of the key projects in the national strategicplanning of West-to-east Power Transmission
Nine sets of CFB boilers with 300 MW capacity
have been put into operation
The first Chinese-built CFB boiler of 300MW wascompleted in June 2006, making a record inmaintaining continuous and safe operation for
more than 142 days

2. General Description ofDomestically Applied
300MW CFB Technology

Comparison between Domestic & Imported 300MW CFB Boilers
Item

Imported Boilers

Boilers for Honghe Project

Total Project Price

1.8 billion RMB/unit

2.4 billion RMB/ two units

Cost for CFB Boiler

0.5 billion RMB/unit

0.26 billion RMB/two units

Installation Period25.5 months

18 months

Commissioning Period

4.5 months

25 days

Boiler Efficiency

91.9%

92.8%

Maximum Load

/

335MW

Continuous Operating Time70 days

142 days

Mechanical Incomplete
Combustion Heat LossNOx Emission

/

0.5%

153 mg/Nm3

139 mg/Nm3

SO2 Emission

563 mg/Nm3

330 mg/Nm3

Auxiliary Power Ratio

7.53%

7.86%

~ 16 t/h

Estimated ~ 4 x 2500 t/h
CycloneRear-passAshes : 28 t/hCombustor
d50 ~ 165 µFilter

200 t/hCoalAirheater~ 0 t/hlimestone

2x
750 t/h
ITS1

ITS2
2x
500 t/hLTS

Ash extraction~ 26 t/hHTR
d50 ~ 25 µ
Ash extraction ~ 12 t/h

d50 ~ 380 µ3. Experiences andAchievements in
Installation & Commissioning

(1) Early Stage Preparation••

In-depth feasibility study
License transfer & risk control

(2) Project Execution Quality• Perfected quality guarantee system• Effective implementation of relevant
regulations and rules

(3) Innovations on Commissioning
Technologies• Trial run on large funs
• Boiler acid cleaning• Boiler dry-out

4. Achievements in
Stable Running &Environmental Protection Impact

(1) Statistics on Accumulated Power Generation Capacity andEquivalent Availability Factor
From Operation Date toJune, 2007
Unit 1
Unit 2
Power Generation Capacity

From January to June,
2007
Unit 1
Unit 2220866.6

178539110432.4111424.2

Period Hours

9420

7366.03

4344

4344

Service Hours

8518.156590.65

4042

4040

Available Hours

9110.77184.03

4344

4163

Utilization Hours

7367.745951.33686.63714.14

Reserve Shutdown Hours

592.55593.58302

122.2

Equivalent Unit Derated
Hours
Forced Outage Hours

186.93

60.37

20.12

5.12

309.3

181.8

0

181.8

Equivalent availability
Factor(%)

94.73

96.71

99.54

95.7

(2) Reflected Characteristics of High
Efficiency and Environmental Protection•••

Adoption of Limestone FGD Technology
Adoption of Low Temperature
Combustion Technology
Application of Twin Chamber ESP with
Five Electric Fields

5. Experiences & Innovations
on Operation & Maintenance(1) Experiences and Innovations on Operation•

Analysis of reasons for “bed-turnover”, formulationof relevant prevention measures and elimination oftechnical problems•

Selection of appropriate coal-feeding temperature toshorten start-up time and reduce oil consumption
during the start-up•

Adoption of start mode by combining HP cylinderand MP cylinder to solve problems brought about by
high heat capacity of circulated solid materials

CFB机组运行难点和解决策略

易翻床

低床压火
焰锋面

高床压火
焰锋面

22kPa
18kPa

30%BMCR 90%BMCR

当发电机解列甩负荷工况或机组并网前定速阶段，由于旁路的投用，再热器系统冲压，高排逆止门开启不充分，造成
高压缸鼓风现象加剧，通风阀系统的加装改造，完善了高中压联合启到方式，
有效的解决了这一难点。

高排逆止门

通风阀

W

堆焊区

侧水冷壁

堆积的
床料起
到防磨
作用

耐磨耐火浇注料

前后水冷壁

(2) Technical Breakthroughs on Maintenance•••

Adjustment of diameters of the coal particles andmixed firing of poor quality coal in certain proportion
stabilizing the furnace bed pressure
The application of domestic high-pressure
centrifugal fluidizing fans in 300 MW CFB boilers forthe first time with three fluidizing fans in smooth
operation and other two in reserve
Adoption of non-metal expansion joints in burners
with blowing channel to solve the technical problemsof expansion displacement in three directions for
300MW CFB boilers

• Removal of the air-heaters on outlet of secondary
air fans to reduce resistance on the outlet• Change of embedded scraper coal feeders fromthree to two feed ports for both stable operationand lower auxiliary power ratio• The horizontal parts of the four return valve arcs
changed from bricking to pouring for morereliable and stable unit operation• Removal of above-bed oil guns according to thecoal quality so as to reduce fluidizing air
consumption• Analysis and summarization of tear and wear toefficiently prevent leakage of Four Pipes in the
boiler

不合理的火焰锋面过渡区

合理的火焰锋面

煤粒
破碎

燃烧的炭粒
密相
区

CFB锅炉设备故障及解决策略减小hh

加装不锈钢网
增加蒙皮厚度不锈钢网分离器壳体

楔形耐磨耐火砖

保温砖

拉钩

膨胀缝

直砖

拉钩砖

6. Concluding Remarks

Thanks！

Day 1 Monday 15 October 2007
Session 3: Clean Coal Power Generation

Speech 3 Korea
Clean Coal Utilization in Coal-Fired Power Plant

Dr. Sungchul Kim
Group Leader
Combustion & Thermal Performance Group
Korea Electric Power Corporation (KEPCO)
Korea

Clean Coal Utilization in Coal fired
Power plant
Korea Electric Power Corporation
Korea Electric Power Research InstituteOct. 15 2007

Combustion & Thermal Performance Group
Group Leader Sung-Chul Kim

Contents

 Energy status of Korea
 Status of 200MWe CFB boiler for clean coalutilization (Past)
 General introduction & the present state of
IGCC in Korea (On-going) Oxy-fuel combustion on power plant (Future)

The Present State of Korea Energy Industry(1)The main indices of energy in the world(’05)
Electric Power
Consumption(11th; ’04))’04))

EnergyConsumption(10th)

Energy Consumption &Intensity
7.91

8Energy Cost
Portion in the
Total Import(25.5%)

Crude oil
Import(5th)&Consumption(7th)EnergyDependency
on Overseas(96.4%)

Ref.: Key World Energy Statistics from the IEA(2006)-2004

Personal Consumption (TOE)

0.3

0.35

(Energy Intensity (TOE/GDP 1000$)

0.22
6

4.43

4.22

3.90

4

4.43

4.18

0.19

0.2

0.18

0.15

0.1

2

0.11
0

0
Korea

USA

Japan

BritishFranceGermany

Korea

USA

Japan

• Personal energy consumption is similar to the advanced countries
countries but the energy intensity is highFranceGermany

BritishThe Present State of Korea Energy Industry(2)Change of the Basement of Energy Policy
1970’sStabilizing energy supply for economic growing

1980’sDiversification of energy source (Nuclear, Natural Gas,
Bituminous)

1990’sRationalization of energy usage/Liberalization of energy market

2000’s

New energy policy for continuous growing

Decreasing of the dependence on oil

61.1%
(’80)

53.8%
(’90)

45.6%
(’04)

5 / 27

44.4%
(’05)

Forecast of Energy Demand
Global & Korea Energy Demand (2015)
Demand for 1st Energy;
2.7% increased by
the annual average

GlobalKorea

Demand for 1st Energy;
3.0% increased by
the annual average

Total Energy Demand;around 3% increasedby the annual averageElectricity Demand;
3.2% increasedby the annual average

Forecast of Korea domestic Electricity Demand
Electric power demand in 2015 :456,443MkWh (1.4 times larger than
than the demand of ’05 (332,413 MkWh)
MkWh)
Maximum electric power in 2015 : 69.47MkW(after demand management(7.82MkW)/1.3
management(7.82MkW)/1.3 times larger than the demand of ’05
Electric power portion of the total energy : 16.6%(’
16.6%(’05) → 18.9%(’
18.9%(’10) → 20.8%(’
20.8%(’15)

7 / 27

Long-term Electric Power Development Plan
(Based on the 3rd Electric Power Demand & Supply Plan)
92,918MW

Capacity
X 1,000 MW

13.0%

78,409MW

90

2.6%

80

62,258MW

70

8.8%
7.6%

60

13.2%
6.1%

28.1%

26.0%
•Re-newable Energy

26.4%

28.4%

50
40

30.8%
28.9%

30
20

- 2010 : 1.6%
- 2015 : 2.2%

27.9%
23.9%

28.5%

10
[Ref. : National Electricity Development Perspective]

0

2005
Nuclear

2010
Coal

LNG

2015
Oil

Hydraulic/etc.

The Present State of Power Plant Capacity
Power Plant Capacity & Generation (2006)
Power Generation

Plant Capacity
4,790

68,1097.3% 8.4%

26.6%

16,766

17,716

5,485

27.0%

17.9%

5,531

148,749

4.4% 1.4%
39.0%

28.2%

36.5%

18,465

139,170

17,436

Total: 65,514 MW
Nuclear

Coal

Total: 380,964 GWh
Gas

Oil

Hydraulic•Mass/Alternative Power Capacity: 1,622MW• Mass/Alternative Electric Power Generation : 2,939GWh
12 / 27

The Present State of Electric Generation
A Daily Curve of Electricity Generation

Hydraulic(Pumping water)

50
Load

40

General
Load

LNG
Oil

30

Coal

20

Base
Load

10

Nuclear(GW) 01

1020

24 (Time)

Coal demand fields in Korea

Mil. Ton
90.0

80.0

80.0

석탄
Coal

70.0

70.0

유연탄
Bituminous

60.0

coal
무연탄
Anthracite

60.0
50.0

50.0

40.0

40.0

30.0

30.0
20.0

20.0

10.0

10.0

0.0

0.0
80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05

YearCoal Import countries in Korea
A u s tr a lia
CanadaC h in aUSA
R u s s ia
In d o n e s ia
e tc .

28
24

Mil. Ton

20
16
12
8
4
0

2002

2003

2004

2005
(Mil. Ton)

Year

Year

Australia

CanadaChina

USA

RussiaIndonesia

Etc.

Total

2002

25

4

25

0

3

6

1

64

2003

25

4

26

0.9

3

6

1

65.9

2004

29.1

4.5

21.3

0.6

5

11.2

0.4

72.1

2005

29.8
(43%)

4.1
(5.9%)

18.1(26.1%)

0.8(1.2%)

3.5(5.0%)

12.9(18.6%)

0.1(0.2%)

69.3(100%)

Purchasing Spec. for Thermal Coal of 5 ElectricPower Companies in Korea

Item

Unit

Limit of Range

Total Moisture (TM) (As received basis)% WTMax. 15

Volatile Matter (Air dried basis)
Fixed Carbon (Air dried basis)
Ash (Air dried basis)

% WT
% WT
% WT

Min. 22~Max. 45
Max. 60
Max. 17~18

Total Sulphur (As received basis)% WTMax. 1.0

Grindability (HGI)

Min. 40~45

Gross Calorific Value (As Received Basis)
Net Calorific Valuekcal/kg
kcal/kg

Min. 5,700~6,000
Min. 5,350~5,750

Nitrogen (Dry ash free basis)% WTMax. 2.0~2.4℃

Min. 1,150~1,200

% WT
% WT
% WT

Max. 16
Max. 2Max. 3%%%Max. 5Max. 40
Max. 17

Ash Fusion Temperature IDT (Reducing Atmosphere)
Ash Analysis
Fe2O3
Na2O
K2O
Size Distribution
Above 50mm
Under 2mm
Under 0.25mm

Status of 200MWe CFB Boiler in Korea (Past)
Tonghae Thermal Power Plant CFB: the largest CFB boiler in Korea (200MWe x 2 units): using Korean anthracite (very low quality coal - high ash content): successful operation since 1998(unit 1) and 1999(unit 2): a combustor, three cyclones and loopseals, three FBHEs, a FBAC and backpass• Ash Pond

• Indoor Coal Yard

• CFB Power Block• Main OfficeTonghae CFB Boiler Features•The Tonghae thermal power plant CFB boiler was designed tofire Korean anthracite by Combustion Engineering, Inc. [ABBCE, 1994] andBackpass•The Tonghae CFB combustor consists of feeding parts of coaland limestone, PA, SA and FA supplier, main combustion part(furnace, cyclones, sealpots, FBHEs and FBAC), and convective
backpass.

Gas Flow
Gas Flow

Coal Silo
CycloneBoilerSolid Flow

Analyses of design coal

Solid Flow

Proximateanalysiswt.%

Ultimateanalysis

wt.%(dry basis)

Moisture
Volatile
Matters
Fixed Carbon
AshHeating Value(dry basis)

3.3
4.0

C
H
O
N
S
Ash

54.7
0.3
3.8
0.2
0.6
40.4

53.7
39.0
4,600
(kcal/kg)

Air

FBHE
Air

WindboxFBAC
Primary Air

Air

General Introduction & the Present State of
IGCC (On-Going)
IGCC : Integrated Gasification Combined Cycle
The Feature of Technology
An integrated power generation technology using purified coal gas (CO, H2)
in the gas turbine and heat of the exhausted gas from the gas turbine and thegasifier in the steam turbine• High efficiency : 39-43% (in case of using high efficiency GT : 45-46%(HHV, Net))• Environment friendly technology : DeSOx rate 99.9%, NOX 25 ppm• Various industrialized process : Texaco, E-gas, Shell, PRENFLO, MHI
A Weak Points :• High investment cost, Complex system, Requires a large Plant Area
• Requested system optimization and cost reduction

IGCC vs. Conventional PC Power Plant

Emission
Plant

Firing Type

Mean Temp. In
the Furnace(℃)

Heat Effi.
(%, Net)

IGCC(300MW)

Coal Gasification

1500

YoungHeung(800MW)

Pulverized Coal
Firing

1100~1200

1)
2)
3)

SOx Reduction(%)

NOx exhaust
(ppm)

40~43

99

25

391)

952)

403)

Test results for electric power transactions in 2005
Design efficiency of FGD in & out
Average exhausted amount in 2005

IGCC Demo. Plants

Major Technical Problems

Target for Research and Development
Final Target
Ensuring of Korean IGCC technology by means of achieving design technology
in the 300MW class and construction of demonstration plant

Heat efficiency: Over 42%(HHV, Net)

Plant Efficiency(%)

Quantitative Target
NOx: Under 30 ppm, Under SOx: 15 ppm
Self-supporting of technology: Over 90%
Equipment localization: Over 90%

Japan

KoreanCCP(2007) IGCC(2012)“Construction of World Best IGCC plant”

Target for Research and Development
Phased Target
3rd Step
2nd Step
1st Step’09.12~’12.11(3yrs)’06.12~’09.11(3yrs)

Development of design & key
technology of demo plant

Construction of IGCC
demo plant-Cooperation of Gasifier
design technology-Demo plant design-Demo plant manufacture& construction-Demo plant test operation-Development of key
technology of coal gasifier-Preparation of construction
plottage-Development of demo
plant operation technology-Development of key
technology’12.12~’14.11(2yrs)

Operation & Improvementof demo plant

Actual Operation &Technology
Improving of
Demo Plant
in the 300MW classContents of R&D
Organization of IGCC Project1z Engineering tech. of gasifier plantz Design & manufacturing tech. of gasifying plantz Localizing of unit process design & manufacturing tech.

[ R&D area of IGCC Project]
Gasifier

Plant Design

Design(Cooperation)

Localizing of
keytechnologies

Development of Gasifier Design Technology(Heavy Industries & Institutes)

2

Total Design, Manufacturing & Construction of
Demo Plant (Power companies)z Total design & construction management of IGCC plantz Preparation of space of demo plant & environmental effects
assessmentz Demo plant manufacturing & construction

IGCC Plant

Plant
Construction

3

Development of Demo Plant Operation technology(Power companies & Institutes)
z Actual operation & improving of demo plantz Combustion technology of IGCC gas turbinez Operation monitoring & simulation of IGCC plant

Actual operationof plant

4

Localization of Unit-Process Technology(Institutes & universities)z Establish of test bed of gasifyingz Localization of DeSOx & DeDust process

Development of design technology of gasifying plant(Heavy industries, Institutes)
Absorbing design technology of gasifying plant, and Localizing it{ Development of design and manufacturing technology of gasifying & gas purifying process
through a technical cooperation (import PDP)
- Localization of unit processes (gasifying, purifying process)Total Plant Design
Technical
Cooperation(Overseas)

PDP
PDP

Localized plantdesign technology
Oxygen plant

Gas turbine
SystemGasifier
Localization
Of unit process(Domestic)

Purification
plant

IGCC Plant Design※ PDP (Process Design Package)Total design, manufacturing & construction ofdemo plant (Power companies)
Power companies’ research area for construction of demo plant• Total design of demo plant & construction management• Preparation of construction space & environmental effect assesment• Equipment manufacturing, purchasing & construction

Road map of demo plant construction
1st Step (3yrs)

Technical
Cooperation

Basic
For
DesignSelectingGasifyingprocess
Developing
company

Environmental
effect assessment(for 20months)

3rd Step (2yrs)

2nd Step (3yrs)

300MW IGCC Plant
Engineering

Approvingofexecution

Contractforordering

Basic plan The
for constr- selectiuction
on ofa site300MW IGCC Plant
Procurements & Construction

Test
operation

Actual operation/Equipment improving

Equipment
manufacturing/purchase
Construction of demo plant in the 300MW
Test
operat-ion
class
Development of simulator& training of test
operator

The permitof thecompletion

Actual operation ofplant

System stabilizing &improvement

Strategy for R&D Propulsion
RDD&D Strategy
 Ensuring Design Technology ⇒ Demo Plant Construction ⇒ Technology
Diffusion & Propulsion of Additional Construction※ RDD&D : Research, Development, Demonstration & Deployment

Ensuring Plant
Manufacturing,
Construction & Operation
Technology

Ensuring Plant
Design Technology(Localization over 90%)z Cooperation withadvanced gasifying
process holding
companies
z Import several part ofcommercial IGCC design
technologyz UpUp-Grade of localized
technologies
z Localization of plantdesign technology over90%

Technology Diffusionz Plant construction(3yrs)’06~’09(3yrs)

ㅇ Efficiency >42%, NOx<30ppm
NOx<30ppm
SOx <15ppm
ㅇ Construction Place: Taeanz Actual operation(2yrs)
ㅇ Operation technology,
Ensuring reliability ,Technology improvement’09~’14(5yrs)

z Replacement ofdomestic obsolescentpower plantㅇReplace obsolescent PC
Power plant to IGCC by
localized technology
zPropulsion export
commercial plant tooverseasㅇ China & Asian Country’14~

The Present State of Exhaust Green House Effect Gas
Korea is expected to be the obligatory reduction country by Tokyo Protocol during 2nd
commitment period; ’13-’18
 The national income will be decreased up to 21-36% in case of reducing the 140 Mil.
ton (based on ’97) of CO2 by 2010 (Economy Institute of Samsung)Actual technology needed to correspond with the state of obligatory reduction

The State of Korea
 GHG Emission : 10th in the world• 580 Mil.ton/yr(’03)
 CO2 : 510 mil-tonCO2/yr(87.9% of GHG )84% CO2 from Power Generation

Fixed Exhaustion Source
3.2 Mil. tCO2/500MWe-unit

 Coal firing power plant : 1.15 Mil. Ton CO2/yr• 23% of total CO2 exhaustion
 78% of total power generation•( Including Heavy oil: Max. 84%)

Ideal target for Apply CCS Technology(CO2 Capture & Storage)Oxy-Fuel Combustion on Power Plant (Future)

Trend of CO2 emission in Korea

Why Oxy-Fuel Combustion?
Advantages• Direct recovery of high purity CO2(>80%)• High reduction in NOX formation and Improved heat transfer• Lower flue gas output(21%) for purification to remove othersecondary pollutants and employs physical separation processes withzero sorbent or solvent residues arising from adding CO2 capture• Relatively little development work left
• The technology giving lowest cost at present(COE: ~45EUR/MWhe)(IEA GHG PF 2004 post.comb.:~47EUR, Mitsui Babcock 2004 Oxyfuel:~45EUR, IEA GHG IGCC 2003 pre.comb.:~47 EUR,
source: Vattenfall AB)

Disadvantages• High cost of oxygen production(~0.5 kWh/m3-O2)¾ Advanced oxygen membranes could lower energy consumption

CO2 Capture Technologies
Post-combustion capture
Capture of
CO2

EnergyConversion

FossilFuel

ASU

Oxy-fuel combustion

EnergyConversion

Capture of
CO2

Energy/Power

Storage/Useof CO2Pre-combustion de-carbonization
Gasification
or Reforming

CO
Shift

Fuel gas
extraction

Energy/Poweror Hydrogen

Energy Efficiency of Oxy-Coal Combustion
Conventional combustion
O2/CO2
Without CO2
recovery

MEA*(Oxy-Coal
Combustion)

CO2 revery rate
Gross capacity
Net capacity
Gross efficiency
Net efficiency

1000MW
946MW
41.4%
39.1%

90%
840MW
672MW
34.7%
27.8%

90%
1000MW
720MW
42.9%
30.9%

O2production/CO2liquefaction
CO2adsorption/CO2liquefaction
Other utilities

54MW

38/72MW58MW

147/108MW
25MW▪MEA: Monoethanolamine, a typical absorbent used for CO2 recovery inconventional coal combustion(the largest energy loss: oxygen production) ← (electrolysis for hydrogen) Source: prof, ken Okazaki, TIT(NEDO-IHI)

Realization of Near Zero Emission

 Oxidant for Coal : Air → Pure Oxygen Condensation of flue gas : capturing most of CO2 & Environmental effect material
 Recycle of flue gas : matching for heat transfer characteristics & CO2 condensation(>80%)
 No CO2 exhaustion by capturingVisionSustainable Energy
Initiative
Solution for Global Environment in Fossil Energy

Steady Supply of Energy

De-Cabonized
Energy Society

Nuclear Fusion Energy, ReRe-newable Energy
Next Generation Nuclear Energy, Clean Coal Energy

Economical Urgency : before 2030

CO2 Capture & Storage

Hydrogen Energy System
Structuring Hydrogen Production/Supply SubSub-System
Application Technology : Fuel Cell

Strategy fortaking in the CCS
market

CO2 Capture
Oxy-Coal
Combustion

CO2 Storage
Geological
Storage

Assessment of Technology

Pre-Capturing

PostPost-Capturing, CO2 transform
Next generation CCS : ITM, CLC

Cooperation with IGCC
Participate in Future Gen ProjectTarget for The Planning Project

The Direction

The Target

Business Model Based on Consumer Focused

Technical Targets
Environment : Near-Zero Emission
Cost : 30€/tCO2-CCS
Performance : Combine with USC
Capacity : 500MWeTime : Actual proving before 2020
In the class of 100MWeTarget period : 2018

Government : Correspond with the ClimateagreementPower Company : Ensuring of Capture
Readiness
Volunteering Company : Making business of
CCSEquipment Company : Growing motive for
equipment industry
Strategy for getting in the mid
The role of industry circles is importantStrategy for Fusing & Mixing
CO2 Capture & Storage
Improving the system of CCS

Policy/Business Model Targets
Development for taking in strategy for
CCS market
Correspond with Climate Change
Agreement
Development of Treatment Inventory• Domestic Inventory• Oversea Inventory : Development of CDM

Structure of the Planning Project
Utilization Technology
Sea Disposal•Transform Technology •Sea Dispersion•Fixing Technology•Sea Under flow

Coal Bed•ECBM

Oil& Gas Field
•EOR
•EGR

Salty Water Bed•Land•OceanCO2 Treatment Technology
The
The Planning
Planning Management
Management•• (Business(Business Model)
Model)
9Corroboration
9Corroboration
9Growing
9Growing Energization
Energization
9Relevant
9Relevant System
System Improvement
Improvement•CorrespondwithClimate•Correspond with Climate Change
Change Agreement
Agreement•StrategyforEnsuringof
CDM•Strategy for Ensuring of CDM

Cooperation with IGCC Project

SystemSystem Unification
Unification•• Optimization
Optimization ofof CoalCoal Firing
Firing PowerPower Generation
Generation•• Boiler
Boiler ++ Capture
Capture Technology+COTechnology+CO22 Treatment
Treatment

PrePre-Combustion
DeDe-Carbonization

PostPost-Combustion
CO2 Scrubbing

OxyOxy-fuel Combustion
Comb/Boiler

3 Elementary Technologies for CO2 Recovery in
the Coal Firing Power Generation Area

Environment
Environment Control
Control••De-Sox
DeDe-Sox••Oxygen
Oxygen Production
Production••CO
CO22 Recovery/Compression
Recovery/Compression

International R&D Trend : Oxy-Fuel Combustion

Key issues with Oxy-Fuel Combustion

9 O2 Production
9 Burner & Boiler Development▪ CO2 Recirculation▪ O2/CO2 Combustion▪ Slagging & Fouling▪ Furnace & Boiler material

9 Plant Operation & Safety▪ Start-up, Turn-down, Air infiltration

9 CO2 Clean-up & Compression

Sequestration Projects WorldwideYear

Size(MM tons
CO2/yr)Summary

Sleipner

1996

1.0

• CO2 captured from off-shore natural-gas-processing platfrom.
injected into saline formation• Project motivated by net tax on CO2 emissions.

Weyburn2000

1.5• CO2 captured in ND, piped to Saskachewan.
• Significant modeling and field testing of CO2 monitoring
equipment

In Salah

2004

1.2

•CO2 captured from natural gas processing and reinjected toenhance gas recovery

Snow White(Snohvit)

2006

0.75

•Need to purify gas before liquefaction(raw gas 5~9% CO2)

project• Project in planning stages, leaning toward EOR combined with
Post-combustion or oxyfuel

CCPC
Gorgon2007

4.0• Need to purify gas before liquefaction(raw gas 12% CO2)

Alaska gas pipeline project

2009

12

• Need to purify gas to meet pipeline stndards(Prudhce Bay raw
gas 12% CO2).
•CO2 capture qualifies for 15% EOR tax credit.

Stanwell• Part of Australia’s clean coal program.

Hypogen• Pre-feasibility study completed January 2005.
• EU version of Future Gen

Innovation Center Initiative(North Sea EOR)

• Large-scale proposed project to help Europe meet Kyoto limits
and extend productive life of North Sea fields.
• CO2 source unspecified.

Sequestration Projects Worldwide
Project

Year

Size

2004

• Initial inj.:30kt/yr• 2006+:0.4MMt/yr• Total:8MMt• Enhanced gas recovery demo project2004• Designed:20t/d• Achieved:1-1.3t/d• Total:3Mt• Injection into coal seam has been more difficult than expected.
• Horizontal wells have been drilled.

K12B

RECOPOL

Summary

Hokkaido

2004• Injection rate:2t/d• Total injected:24t• CO2-ECBM test project• Spring 2005 wells will be refurnished(original cementing notsatisfactory) and new more extensive CO2 injection test planned

CASTOR2004• Rate:10kt/yr• Conducting pilot-scale tests of post combustion capture and casestudies of four potential geologic storage sies.

Quinshi2005• Total injected:200t• Duration:22d• Next phase of the project will involve multi-well test, design of which
will be complete in 2005

Otway

Late
2005

• Rate:160t/d• Duration:2yrs• Total:0.1MMt• Planned pilot-scale project.
• Saline formation and depleted gas field2006• Rate:30kt/yr• Duration:≥2yr• Project to test and evaluate CO2 capture and storage at an existing
natural gas storage facility and in a deeper land-based saline
formation

CO2 SINK
ARC ECBM
Recovery Project• Pilot-scale project (3 test wells)

CO2 Geological Storage Worldwide

Summary
O The role of coal as a fuel of power generation in Korea is more significant
O Bituminous coal consumption is increasing annually( Korea is the 2nd largest importing country in coal)
O IGCC appears to be the economic choice for power plant market( High Efficiency & Clean Emission)O CCS is the critical enabling technology because it allows significant
reduction in CO2 emissions▪ Oxy- fuel combustion is now emerging technology

Day 1 Monday 15 October 2007

Session 4:
Coal Demand Outlook 2

COAL DEMAND OUTLOOKIN THE PHILIPPINESAPEC CLEAN FOSSIL ENERGY SEMINAR
15 – 17 October 2007
Xian, China

Restituto G. Taganas, Jr.
DEPARTMENT OF ENERGY, PHILIPPINES

ENERGY POLICYandSTRATEGIC COAL POLICYFRAMEWORK
for thePHILIPPINE ENERGY PLAN
(2005-2014)

ANTI-CORRUPTION
THROUGH GOOD GOVERNANCE

ENERGYINDEPENDENCE
SOCIAL JUSTICE
AND BASIC NEEDSEDUCATION
AND YOUTH OPPORTUNITY

ENERGY SELF-SUFFICIENCY

ENERGY SECTOR AGENDA

FIVE-POINT REFORM PACKAGEECONOMIC GROWTH
AND JOB CREATION• Accelerate exploration, development and utilization ofindigenous energy resources• Intensify development of renewable energy resources
such as biomass, solar, wind, and ocean resources• Increase use of alternative fuels• Enhance energy efficiency and conservation program• Form strategic alliances with other countries
EFFICIENT AND GLOBALLY COMPETITIVE ENERGYSECTOR• Establish a transparent privatization process• Create an investment climate attractive toinvestors

Revitalizing the Exploration and Developmentof Indigenous Resources - COAL
Strategic Plans¾ Continue the offer of prospective areas under the Philippine Energy
Contracting Round (PECR)¾ Implement the following projects:
 Assessment of the Coal Bed Methane (CBM) and other related coalresources
 Mine safety, rescue and emergency preparedness in coal mining Coal mine to market linkage program¾ Finalize the amendment of the Small-Scale Coal Mining Circular¾ Finalize the revision of the Coal Mine Safety Rules and Regulations¾ Finalize the new Circular providing the guidelines for Coal Bed Methane(CBM) exploration, development and production

HISTORICAL CONSUMPTIONHISTORICAL COAL CONSUMPTION(Years 1977 – 2006)
9,000,000

8,000,000

7,000,000

6,000,000

5,000,000

4,000,000

3,000,000

2,000,000

1,000,000

1977

1979

1981

1983

1985

Power Generation

1987

1989

1991

1993

Cement

1995

1997

1999

2001

2003

Industrial/Direct

2005

HISTORICAL PRODUCTION, CONSUMPTION & IMPORTATION(Years 1977 – 2006)
12.00010.000

8.000

6.000

4.000

2.000

0.000

1977 1979 1981 1983 1985 1987 1989 1991 1993 1995 1997 1999 2001 2003 2005 2007

Consumption

Production

Importation

CURRENT DEMAND FOR COAL

COAL CONSUMPTION(Year 2006)

4%

23%

73%

POWER

7,529,779 MT

CEMENT
IND'L/DIRECT PROCESS

2,117,654
414,541

Total

10,061,974 MT

EXISTING POWER PLANTS CAPACITY

Oil Thermal
4.10%

Wind Solar
0.16% 0.01%

Coal
26.35%

Hydro
20.54%
Geothermal
12.79%Natural Gas
17.43%

Gas Turbine
6.02%

Diesel12.60%

Energy Situationer

PRIMARY ENERGY SUPPLY MIX
2000

2006
Oil
37.53%

Biomass
24.80%

Biomass
15.70%

Others0.02%
Oil35.25%

Geothermal
22.89%

Coal
10.06%
Hydro
4.45% Natural Gas
0.26%

Self-sufficiency Level = 54.2%

Geothermal
22.84%

Coal
13.49%
Hydro
6.28% Natural Gas
6.42%

Self-sufficiency level = 55.8%

POWER GENERATION MIX

2000

2006

Natural Gas
0.04%
Coal
36.79%

Oil
20.28%

Geothermal
25.67%

Total: 45,290 Gwh
Self-sufficiency = 43%

Hydro
17.22%SW
0.10%

Natural Gas
28.82%

Coal
26.93%

Hydro
17.50%
Geothermal
18.43%

Total: 56,784 Gwh
Self-sufficiency = 66%

Oil
8.21%

FUTURE DEMAND FOR COAL

COAL SUPPLY AND DEMAND OUTLOOK(Years 2006 – 2014 , in 1000 MT)
18,00016,00014,00012,00010,000
8,000
6,000
4,000
2,000
-

2006

2007

Demand

2008

2009

2010

Production

2011

2012

2013
Imports

2014

COAL DEMAND OUTLOOK(Years 2007 – 2014, in 1000 MT)
14,00012,00010,000
8,000
6,000
4,000
2,000
2007

Power Generation

2008

2009

Cement

2010

2011

2012

Steel

2013

2014

OthersCOAL SUPPLY AND DEMAND OUTLOOK(Unit: 1,000 TCE)
Calendar Year

2006

2007e

2008

2009

2010

2011

2012

2013

2014

(A)

2,644

2,910

2,082

3,400

3,790

4,079

4,606

4,736

5,241

From Asian region

4,732

5,730

5,975

6,107

6,369

6,338

6,160

6,304

6,202

From other regions

525

637

664

679

708

704

685

701

689

total

5,257

6,367

6,639

6,786

7,077

7,042

6,845

7,005

6,891

7,901

9,277

9,721

10,186 10,867

11,121 11,451 11,741

12,132

Production
ImportExport(B)

From Asian region
From other regions
total

(C)

Total Supply (D) = A+B-C
Domestic
Supply to

Power

a

6,296

7,654

6,079

6,224

9,185

9,418

9,729

9,998

10,369Iron & Steel

b

205

208

210

213

215

218

220

223

225

Cement

c

1,348

1,363

1,380

1,396

1,413

1,430

1,447

1,464

1482

Others

d

52

52

52

53

54

55

55

56

56

Total Demand (E) – a+b+c+d

7,901

9,277

9,721

11,121 11,541 11,741

12,132000Balance (F) = (D) - (E)10,186 10,867
0

0

0

0

0

0

POWER GENERATION MIX
2010

2014
OthersWind
oil-based
3.05%
0.29%
3.36%

oil-based
3.36%

Wind
0.24%

Others
17.38%

Geothermal
14.93%
hydro9.63%

Natural Gas
19.59%

Coal
34.87%

Hydro
11.72%

Geothermal
17.26%

Coal
39.68%Natural Gas
24.63%

PRIMARY ENERGY SUPPLY MIX
2010

Solar, Wind &Micro-hydro
0.32%

2014

CME & Ethanol
1.01%
Biomass
25.25%

Oil
11.41%

CME & Ethanol
Oil
1.08%
6.81%
Natural Gas
9.37%
Coal 8.55%

Hydro
8.04%

Geothermal
36.05%

Solar, Wind &Micro-hydro
0.30%

Hydro
7.44%

Biomass
24.54%Natural Gas
14.05%
Coal 10.89%

Geothermal
34.90%

Summary of Regional Coal Reserves (MT)As of December 31, 2006
Resource
Potential
Cagayan Valley
Cebu
CentralNorthern
Southern
Davao
MasbateMindoroNegrosPolillo, Batan &Catanduanes
QuezonSamar
Semirara
Surigao
Zamboanga
BukidnonMaguindanao
Sarangani
South Cotabato
Sultan Kudarat
Total

Positive
Reserves

Probable
Reserves

In-situReserves

Mineable
Reserves

336,000,000

80,104,730

3,695,000

82,568,063

70,182,854

40,000,000
75,000,000
50,000,000
100,000,000
2,500,000
100,000,000
4,500,000
17,000,000
2,000,000
27,000,000
570,000,000
209,000,000
45,000,000
50,000,000
108,000,000
120,000,000
230,400,000
300,300,000

3,354,257
2,229,719
1,295,113
208,000
74,994
1,310,641
1,204,952
5,122,494
93,0007,474,890
124,379,660
29,298,653
34,247,148

4,763,160
655,727
1,870,206

1,667,725
43,820,358
60,978,034
5,984,679

6,529,697
2,666,870
2,541,917
208,000
74,994
1,442,641
2,013,877
6,192,531
93,0008,586,707
153,593,232
69,950,676
38,236,934

3,917,818
1,600,122
1,525,150
124,800
44,996
865,585
1,208,326
3,715,518
55,8007,278,807
130,554,247
47,799,580
22,942,161

23,590,423

66,123,516

67,672,767

40,603,660

313,978,674

192,574,467

442,361,652

332,413,274

2,366,700,000

198,000
1,213,387
1,604,675

Salamat Po!
Thank You foryour Attention!

Day 1 Monday 15 October 2007
Session 4: Coal Demand Outlook 2

Speech 2 India
Coal Demand Outlook in India

Mr. KS Kropha
Joint Secretary
Ministry of Coal (MOC)
India

Integrated Energy Policy,
Policy Framework on Coal
and
Coal Demand Outlook
for India(APEC Seminar in Xian)
15th – 17th October, 2007

Energy Security
Definition (Integrated Energy Policy):¾ “We are energy secure when we can supply
lifeline energy to all our citizens irrespectiveof their ability to pay for it as well as meettheir effective demand for safe andconvenient energy to satisfy their various
needs at competitive prices, at all times andwith a prescribed confidence levelconsidering shocks and disruptions that canbe reasonably expected”.
2Energy Outlook¾ 439 kgoe per capita consumption in 2003 – one of

the lowest (1090 in China, 7835 in the U.S. and theworld average of 1688)¾ Low energy intensity of 0.16 kgoe per dollar of GDP(PPP) (China 0.23, USA 0.22, World average 0.21)¾ 8% - 10% economic growth rate over next 25 years
targeted¾ Primary energy supply to increase by 3 to 4 times in
2031-32¾ Power generation capacity/supply by 5 to 6 times(from 160,000 to 800,000 MW)¾ Demand for coal to increase to 2 bn tons

3

Energy Outlook (contd..)¾ Oil demand to increase from 124 Mt (2004-05)

to 281 (2029-30)¾ Natural gas demand to rise from 98 MMscmd to430 MMscmd¾ Total primary commercial energy requirements:
2006-07 z 2011-12 z 2031-32 z

394 Mtoe573 Mtoe1856 Mtoe¾ Commercial energy supply to grow @ 5.2 –

6.1% per annum
4

Share of energy resources

5

Policy Options for energy
security¾ (a) Reducing Risks:• Reduce the requirement of energy byincreasing efficiency in production and use ofenergy;• Reduce import dependence by substituting
imported fuels by domestic fuels;• Diversify fuel choices and supply sources;• Expand domestic energy resource base.
6

Policy Options for energy
security (contd..)¾ Dealing with Risks:
Increase ability to withstand supply
shocks;• Increase ability to import energy andface market risk;• Increase redundancy to deal withtechnical risk.
•

7

Present Policy Regime
for

Coal
8

Importance of Coal Resource to India¾ In commercial energy sector requirement.

coal meets 59%¾ In power generation - coal contributes 75%.
¾ Power sector : consumes 78% of total country’s
coal production.
¾ Other industries such as steel, cement, fertilizer,
paper and others - also dependent on coal.
9Commercial Mining¾

Central Government, a Govt. Company(including a State Govt. company), a
corporation owned, managed & controlled by
the Central Govt.

¾

Private company only in isolated and small
patches under following circumstances:

Reserves are not sufficient for scientificand economic development in an
integrated manner.



The coal produced would not require to
be transported by rail.
10Captive Mining¾

Permitted for iron & steel production in 1976.

¾

For power generation in 1993.

¾

For cement production in 1996.

¾

For coal gasification & liquefaction in 2007.

¾

End user company (allocatee) can get theblock developed through an associatedmining company.

¾

Independent mining company eligible to get a
captive block – provided firm tie up fortransfer of coal to approved end users.
11
Contd…

Captive Mining (Contd…)¾

About 229 coal blocks, with 48 BT ofgeological reserves, identified for allocation to
Govt. companies/approved captive end users.

¾

Interest in captive mining picked up after theinternational coal market trends changed in
2002-03.

¾

165 coal blocks with 37.2 BT geologicalreserves allocated so far.

¾

81 coal blocks with 20 BT reserves on offer forallocation – 41 (with 15.7 BT reserves) for
power generation, rest for other end uses.
12Pricing¾

Administerednationalisation.

¾

The Colliery Control Order 2000 - pricing anddistribution of all grades of coal deregulated.

¾

No regulation on pricing in captive mines.

¾

Peculiar market conditions – single major
producer and single major consumer, limited
interplay of market forces.

price

regime,post

13Foreign Direct Investment (FDI)¾

Policy on FDI reviewed recently.

¾

100% FDI allowed in captive mining of coaland lignite for permitted end-uses.

¾

Under automatic route – no prior approvalrequired.

14

Import¾ Trade regime liberalised – coal placed in OGL.
¾ No import quotas.
¾ Duties reduced:

No duty on coking coal with ash content of
below 12%;Nominal duty of 5% on coal with ash content of
12% and above.

¾ Constraints:
High ocean freight rates;Port facilities;

In-land transport infrastructure.
15

Policy Challenges Ahead¾ Opening up of sector – Huge demand – projected to rise to 1128 MT –1870 MT by 2026-27;
 Increase the number of players – remove entry
barriers.

¾ Production infrastructure – Road and rail network; Human resource;
 Mining equipments manufacturing
within the country

capacity¾ Land acquisition – Becoming increasingly more contentious ; Rehabilitation and resettlement issues;
16
Contd…

Policy Challenges Ahead (Contd…)¾ Technology challenges –Induction of mass production technology;
Focus to shift on UG mining – incentives, if
necessary;
Environment friendly.

¾ Clean Coal Technology –Washeries – encouraged on BOO basis, FDI
allowed;
Exploitation of CBM/CMM;
In-situ gasification;
Liquefaction.
17
Contd…

Policy Challenges Ahead (Contd…)¾ Independent Regulator –Pricing;Standardise norms of operation;
Liberalise
extantregulations
restrictive;

that

are

¾ Allocation of coal blocks through competitive
bidding.
¾ Imports –Upgrade port facilities;
Improve in-land transportation infrastructure.

¾ Greater autonomy to State Owned Enterprises.

18

Coal Demand Outlook

19

Coal : Prime Fossil Fuel Resource
in India¾ Coal is the most abundant fossil fuelresource in India.
¾ India stands fourth in terms of total
World Proved Coal Reserves.
¾ India currently ranks third largest coalproducing country in the World.

20

Coal Reserves in India (Hard Coal)(As on 01.01.2006)(BILLION TONNES)TOTALRESERVE

PROVEDRESERVE

INDICATEDRESERVE

INFERREDRESERVE

COKING

32

17

13

2

NON-COKING(A+B+C) NC

221

79
15

107

35

TOTAL

253

96

120

37

WORLD COAL
RESERVE*

-

519

-

-

% RESERVE IN
INDIA OVERWORLDRESERVE

-

18

-

-

* SOURCE : WORLD ENERGY COUNCIL

21

Sector-wise Coal Offtake (2005-06)

OTHERS
12%
CEMENT PLANTS
4%STEEL PLANTS &COKERIES
9%POWER HOUSES
75%

22

Demand Projection vis-à-vis Past Consumption Trends(Working Group for XI Plan)

Million Tonnes
Sectors

2001-02
Actual

2006-07
ActualCAGR%

2011-12XI Plan

CAGR%

2016-17
XII Plan• Power (U)249.23310.004.46

483.009.27

750.00• Power (C)

16.02

31.50

49.66

9.50

73.00

• Cement+Cmt CPP

15.22

25.00

39.30

9.47

62.00

• Sp.Iron+Other

41.60

50.50

90.64

12.41

135.00Total Non Cok.

322.07417.005.30

662.609.70

1020.0• Steel-Coking

29.84

43.00

7.58

68.50

9.76

105.00Total

351.91460.005.50

731.109.71

231125.0Sectoral Trend In Consumption/Demand(Million Tonnes)

Sl.
No.

Consuming
Sector

70-71

80-81

90-91

2000-01

2006-072011-12(Projn.)**1

Steel & Coke
Ovens

13.5

22.4

27.6

19.67

43.00

68.50

2

Power Utilities

13.2

36.7

116.7

234.60310.00483.003

Power Captive

*

*

12.5

15.93

31.50

49.66

4

Fertilizer

*

2.3

3.9

3.18

5

Cement

3.5

4.8

9.7

10.33

25.00

39.30

6

Railways

15.6

11.9

5.2

-

-

7

Domestic Soft
Coke

4.1

1.3

1.3

-

-

8

Other
Industries

21.8

30.3

30.7

35.96

50.50

90.64

TOTAL

71.7

109.7

207.6

319.67460.00731.10* Included in other industries** As per Working Group Report for XI Plan

24

Projected Availability of Indigenous Coal
SECTORX Plan(06-07)*XI Plan(11-12)**

XII Plan(16-17)

XIII Plan(21-22)

XIV Plan(24-25)CIL

363.80520.50

664

730

782

NON-CIL
UNBLOCKED
AREAS

-

-

-

25

57

TOTAL CIL

366.09520.50

664

755

839

-

-

5

15

25

SCCL

37.50

40.80

45

47

47

OTHERS: CAPTIVE
TISCO/IISCO

31.20

118.70

346

125

175

GRANDTOTAL

432.50680.00

1060

942

1086

COAL EQUIVALENTCBM-UCG***As per Annual Plan 2006-07 of Ministry of Coal.
As per Working Group XI Plan estimates
25

Demand & Supply Scenario(Million Tonnes)
2006-072011-12 2021-22 2024-25

DEMAND

473

731

1079

1267

SUPPLY

432

680

942

1086

GAP

41

51

137

181

CokingNon-coking

41
10
26

Import of Coal
Million Tonnes
1996-97 2001-02 2002-03

200304

2004-05 2005-06

COKING &
COKE

10.62

11.11

12.95

12.99

14.84

12.50

NONCOKING

2.56

9.44

10.31

8.69

10.46

14.50

TOTAL
IMPORTS

13.18

20.55

23.26

21.68

25.30

27.00

COAL
IMPORTS27

Thank you

28

Day 1 Monday 15 October 2007
Session 4: Coal Demand Outlook 2

Speech 3 Korea
Coal Demand Outlook in Korea

Dr. Jaeho Kim
HeadTechnical Research Institute
Korea Coal Corporation (KOCOAL)
Korea

Coal Demand Outlook in Korea
Oct . 2007

Jae Ho Kim
Korea Coal Corporation

CONTENTS

1. The current state of the coal industry in Korea
2. The current Issues of the coal industry in Korea
3. The predicted amount of anthracite’s demand andsupply within mid-period in Korea
4. The directions of policy on a long term for coalindustry in Korea
5. The current state of the import coal1
General properties(features) of Korean anthracite

Low V.M.

About 5%Government had
anthracite about

High Ash

Over 35%

7MT in stock
since 1990.

Low Cal.

About 4,800 kcal/kg

High
High Ignition
Ignition
Temp.
Temp.

200℃ higher than Bituminous coal

Low React.

Low reactivity compare to bituminous coal2
The usage of Korean anthracite

The main usage of Korean anthracite is to manufacture
honeycomb briquette for residential heating fuel.
ㅇ Korean anthracite is used as a fuel in the shape ofhoneycomb briquette for cooking food and heating houses
in winter.

ㅇ Burning experiments proved that it’s impossible to use
the mixture of Korea anthracite and over 15% bituminous
coal as a honeycomb briquette.
Because bituminous coal contains low ash. Therefore, it can’tsustain the shape of briquette after combustion.

ㅇ The Korean anthracite has been distributed to power plant by
the Korean government due to the policy for supporting
domestic coal mines.

3
Honeycomb briquette for residential heating fuel4
Ⅰ. The current state of the coal industry in Korea
1. The promoting policy of reducing coal production
caused by decreased consumption

ㅇ Amount of Korean anthracite production had been risen about 24MT
per year until 1988.
ㅇ Due to the growth of Korea economy, clean fuel is prefer to use insteadof uneconomical efficiency of Korean anthracite.
Therefore, the Korean government has propelled the policy which is
reducing of coal production.
- Coal production has decreased sharply by 10% level because of
the abandoned mines and the policy of a cut in production.
* Domestic coal mines : (’88) 347 → (’07) 7 (△340)5

ㅇ Therefore, the mining regions has been showed- rapidly withered the economic activity- decreased incomes and dwindled population- occurring social problems.

6

2. Production and efficiency
Production in 2006 (Tou.T)

Trend
Efficiency

D.K. : 350
K.D. :1,060(Ton/man shift)

T.B. : 116
T.A. : 282
J.S. : 611

6.652 7.337

Production
3,318 3,299

7.369 7.612

7.877(Thou. Ton)
3,191 2,832

M.R. : 80

2,824

H.S. : 272

2002

2003 2004

2005

2006

7

3. Changes of total production and employees
Production(Thou. Ton)

24,273
2,824

1988

2006

¾88%Down

Coal mining
employees

 Economic

stagnationin the mining
regions

¾ 91%
1988

62,259

Down

2006

5,940

8
3. Anthracite’s demand and supply in Korea

ㅇ Anthracite’s amount of demand and supply in Korea has beenbalanced recently by the government policy which is reducingof coal production.
ㅇ But, nowadays consumption of briquette is increased gradually
because many customers affected by high oil price are changing
their fuel from oil to briquette and freezing of briquette’s price.
ㅇ Therefore, anthracite’s amount of demand and supply was broken
the balance in 2001; production(3.3 MT), consumption(4.5 MT)- The Korean government discharged 7MT of anthracite in stock
for the anthracite’s amount of demand and supply could bebalanced for a while.

9
Ⅱ. The current Issues of the coal industry in Korea
Unbalance of anthracite’s demand and supply
ㅇ The trend of unbalance in coal industry will be expected
to maintain for the time being, since consumption exceeded
production in 2001
ㅇ Briquette consumption is increased sharply over 2MT
after it has maintained 1.2 MT.
Coal production has been decreased by the government
policy and abandoned mines.
ㅇ Therefore, long-term countermeasures for stabilizing
anthracite’s demand and supply should be made.

10III. The predicted amount of anthracite’s demandand supply within mid-period in Korea

1. Demand prospects
ㅇ Demand for briquette is expected to increase 11.1% every year.
ㅇ Demand for coal power plant is expected to maintain thesame level(2,356 Thou. Tons) by the government.
[Mid-term prospect of demand(Thou. Ton)]
2006

2007

2008

2009

2010

Mean ofincreaserate(%)

Briquette

1,985

2,331

2,626

2,868

3,059

11.1

Power
generation

2,356

2,356

2,356

2,356

2,356

-

Industry

147

148

149

150

152

0.8

Total

4,488

4,835

5,131

5,374

5,567

5.3

11
2. Mid-term prospect of anthracite’s demand and supply in Korea
ㅇ The unbalance of anthracite demand and supply is expected toincrease under the present policy of a cut in production.
ㅇ Therefore, the Korean government is considering coutermeasures
for stabilizing anthracite’s demand and supply because stored
anthracite would run out of in 2009.
- Korea Coal Corporation is going to increase coal production[Mid-term prospect of anthracit’s demand and supply(Thou. Ton)]
2006

2007

2008

2009

2010

Mean ofincreaserate(%)

Demand(A)

4,488

4,835

5,131

5,374

5,567

5.3

Product(B)

2,753

2,753

2,753

2,753

2,753

-

Lack(B-A)▲1,735▲2,082▲2,378▲2,621▲2,814

Stock

5,613

3,531

1,153

▲1,468▲4,282

12
Ⅳ. The directions of policy of on a long term
for coal industry in Korea
1.

Long-term countermeasures for stabilizing
Anthracite’s demand and supply<General Direction>
ㅇ Managing simultaneously production and consumption forstabilizing anthracite’s demand and supply in Korea.
- Controlling actively consumption for balancing with production.

13
2. Driving effectively projects for developing
the regions of abandoned mines<General Direction>
ㅇ Boosting economy in the regions of abandoned minesby government subsidies.
ㅇ Developing new industry in the regions of abandoned mines
through making favorable circumstances for business.

14
3. Promotion efficiently overseas businessfor developing bituminous coal mines< General Direction>
ㅇ Developing progressively bituminous coal mines in foreigncountries for increasing self-sufficient rate in energy.
ㅇ Korean government is drive forward some projects fordeveloping bituminous coal mines.

15
Ⅴ. The current state of import coal
1. Status of import coal
- Consumption of the bituminous coal is increased
sharply every year in Korea.
- Korea is the 2nd largest nation about import coalin the world.
- Korea has experienced that controlling of coal demandand supply was very hard when the price of importcoal was rising.
- Obtaining bituminous coal is expected to get harder in
East Asia. Because Korea has few own bituminous coalmines in foreign countries and has to compete with theother countries .

16
2. Status of import coal(bituminous) in 2005(Ton)

Iron and
Steel

Power
generation

Australia

9,929,158

19,488,947

361,014

29,779,119

43.0

China

1,858,261

10,428,538

5,824,926

18,111,725

26.1

0

12,847,471

37,70012,885,171

18.6

Russia461,004

2,497,738

531,967

3,490,709

5.0

Canada3,842,202

275,7080

4,117,910

5.9

U.S.A

795,44200795,442

1.2

Switzerland

56,3970056,3970.1

Singapore

32,9090032,909

0

India

0

60,623060,6230.1

Total

16,975,373

45,599,025

6,755,607

69,330,005

100.0

24.5

65.8

9.7

100.0

Indonesia

Prop.(%)

Cement,Others

Proportion(%)

NationTotal

17
3. The prospect of import coal (bituminous)(Thou. Ton)

2006

2007

2008

2009

2010

75,08078,752

81,68385,58393,361- Power
generation

45,512

47,94049,96752,96759,853- Iron andSteel20,83821,81022,44423,076

23,708- Cement

6,350

6,609

6,868

7,122

7,372

- Others

2,380

2,393

2,406

2,418

2,428

Import● Australia and China account for 70% of Korean market

18
4. Status of coal mine development for bituminous coalin foreign countries by Korean corporations
2005

Australia

U.S.A

CanadaIndonesia

China

RussiaTotal

Product

8

1

1

1

-

1

12

Exploration

2

-

-

1

2

-

5

Total

10

1

1

2

2

1

17

ㅇ Strategic investment nations by Korea :Australia, China, Indonesia, Canada• Thank you for your attention.

Day 1 Monday 15 October 2007
Session 4: Coal Demand Outlook 2

Speech 4 Chinese Taipei
Coal Demand Outlook in Chinese Taipei

Mr. Jin-sheng Su
Director
Electricity Division
Bureau of Energy (BOE)
Ministry of Economic Affairs (MOEA)
Chinese Taipei

苏金胜
出生日期:1955,5,26
现任职务:经济事务部能源局,电力处主任
工作经历:
1979-1980

能源公司, 电机工程师，分配系统设计

1982-1994 经济事务部,能源委员会,计划工程师，能源节约政策及措施的创始，联合发电项目的促进，IPP项目的计划和执行
1995-1996

能源委员会,编辑秘书处

1997-1998

能源委员会,电力处,首席工长

1999-2003

能源委员会,电力处主管

2003-至今能源局,电力处主任1

SuJinsheng
Date of Birth: May 26, 1955
Present Position: Organization:
Director, Electricity Division
Bureau of Energy, Ministry of Economic Affairs
Experience ：2003- Present：Director, Electricity Division, Bureau of Energy
1999 – 2003：Supervisor, Electricity Division, Energy Commission.
- Initiation of 3rd round IPP program.
- Initiation of electricity liberalization policy.
1997- 1998： Section Chief, Electricity Division, Energy Commission.
1995 – 1996： Editing Secretary, Energy Commission.
1982 – 1994：Project Engineer, Energy Commission, Ministry of Economic Affairs.
- Initiation of energy conservation policies and measures.
- Promotion of co-generation programs.
- Planning and implementation of IPP programs.
1979 – 1980：Electrical Engineer, Power Company.
- Design of distribution system

2Harmonious and Sustainable Coal Power Generation

Clean Fossil Energy Seminar和谐与可持续的燃煤发电
清洁的化石能源研讨会
Xian, PRC, 15~17 October 2007

Coal
Coal Demand
Demand Outlook
Outlook ininChineseChinese Taipei
Taipei

中国台北的煤需求前景
中国台北的煤需求前景
Su, Jin-sheng
Director, Electricity Division
Bureau of Energy, MOEA

3

TopicTopic Outline
Outline 主题概要主题概要
Coal-fired Power Plant Map
Coal Supply Structure
Coal Demand Structure
Framework of Coal Policy
Coal Supply and Demand Outlook
Conclusions燃煤发电厂地图
煤供应结构
煤需求结构
煤政策框架
煤供应与需求前景结论4

Chinese
Chinesetaipei
taipeiCoal-fired
Coal-fired PowerPower Plant
Plant Map
Map

中国台北燃煤发电厂地图
中国台北燃煤发电厂地图

5

Coal
CoalSupply
SupplyStructure
Structureby
bysource
source煤供应结构煤供应结构 根据来源划分
根据来源划分Coal production in chinese taipei totaled more than 5 million M.T.
annually from 1964 to 1968.
Coal supply has been totally imported from foreign countries since2001.
从1964到1968年中国台北每年全部的实际煤产量都多于5百万M.T.
从2001年开始，煤的供应全部由外国进口.
million M.T.

62.2

70

49.1

0.0

地产

60
Indigenous

0.0

50
40
30
20
10

Imported

31.2
18.8
12.4
1.7

0.4

0.1

进口

62.2
49.1

31.1

18.4

10.7

0

1986

1991

1996

2001

2006

Year

6

Coal
CoalSupply
SupplyStructure
Structureby
bysource
source煤的供应结构（根据来源分类）煤的供应结构（根据来源分类）Coal supply has been imported totally from foreign countries
since 2001.

从2001年开始煤的供应全部由外国进口.
Imported
100%

Indigenous

进口

地产

2.1%

0.5%

0.0%

0.0%

97.86%

99.53%

100.00%100.00%

1991

1996

2001

2006

13.9%
80%

60%

40%

86.10%

20%

0%

1986

7

Coal
Coal Supply
Supply Structure
Structure bybyimported
importedarea
area
煤供应结构
煤供应结构 根据进口地区划分
根据进口地区划分

Chinese taipei imported 45.4 million M.T. of coal in 2000 and increased to62.2 million M.T. in 2006.
Coal quantity imported from Indonesia and Australia increased from 13.4
to 24.1 million M.T., and 17.6 to 22.3 million M.T., from 2000 to 2006,
respectively.

2000年中国台北进口了45.4百万M.T.煤，到2006年进口量增加到62.2百万
M.T..
从2000年至2006年，从印尼进口的煤数量从13.4百万M.T.增加到24.1百万
M.T.，从澳洲进口的煤数量从17.6百万M.T. 增加到22.3百万M.T..

Total

45,392

51,83870,00024,706
15,97930,00013,441

13,88620,00016,89910,00017,644
2,911

0

517

110

12,651
1,113 398
657

2000

2002

2004

24,087

1,235

1,877

1,000 M.T.
OthersChina
Indonesia
Australia
S. Africa
CanadaU.S.A.

13,036

1,974
1,386
8,258

40,00062,186
1,481

1,662

60,00050,00060,484

19,444
22,332
1,250

967

2006

8

Coal
CoalSupply
SupplyStructure
Structure by
byimported
importedarea
area
煤供应结构
煤供应结构 根据进口地区划分
根据进口地区划分
Chinese taipei imported 45.4 million M.T. of coal in 2000 and increased to 62.2
million M.T. in 2006.
Coal quantity imported from Indonesia and Australia increased from 13.4 to
24.1 million M.T., and 17.6 to 22.3 million M.T., from 2000 to 2006,
respectively.

2000年中国台北进口了45.4百万M.T.煤,到了2006年增加到62.2百万M.T.
从2000年至2006年，从印尼进口的煤数量从13.4百万M.T.增加到24.1百万
M.T.，从澳洲进口的煤数量从17.6百万M.T. 增加到22.3百万M.T..

Total

45.4

51.8

60.5

62.2

million M.T.

3.1

3.8

2.7

2.4

Others21

China

Percentage

100

18.2
30.8

40.8

80

Indonesia

29.6
38.7

60
40
20

32.2

S. Africa

38.9
26.2

6.4

3.6
2.7

0

Australia

33.2

2.2

20.9
0.7

1.1

0.2

1.1

2000

2002

2004

Canada

35.9
2

1.6

2006

U.S.A.
9

SteamSteam Coal
Coal Supply
Supply Structure
Structure by
byimported
importedarea
area锅炉用煤供应结构
锅炉用煤供应结构 根据进口地区划分
根据进口地区划分
China

Indonesia

S. Africa

Australia

OthersM.T.
60,00050,00040,00030,00020,00010,000
0

2001

2002

2003

2004

2005

2006

Year
10

Coking
Coking Coal
Coal Supply
Supply Structure
Structure by
byimported
importedareaarea
焦煤供应结构
焦煤供应结构 根据进口地区划分
根据进口地区划分
CanadaAustralia

China

Other

M.T.
10,000
8,000
6,000
4,000
2,000
0

2001

2002

2003

2004

2005

2006 Year

11

Coal
Coal Demand
Demand Structure
Structure bybysector
sector煤需求结构煤需求结构 根据部门划分根据部门划分Power generation has been the major coal use sector.
Coal demand has grown at an annual growth rate of 18%
over the past two decades.
发电行业已经成为主要的用煤部门.
这20年以来,煤的需求量以每年18%的增长率在增加.
3

10 MT

61,71670,00047,96760,000Coke

50,00018,78030,00020,000Industrial& Others

29,60340,000Power
Generation

13,452

10,000
0

1986

1991

1996

2001

2006 Year12

Framework
Framework ofof CoalCoal Policy
PolicyBackground

Foreign & Domestic
Coal Situation

Coal Market
Liberalization

Environmental
Protection

Coal Policy inchinese taipei
PolicyGuidelines

Stabilizing
Coal Supply

Enhancing
EnergyEfficiency

Promoting
Environmental
Protection

Reinforcing
R&D

PolicyMeasures

Regulate coalreserve insecure quantity

Stress onenergyconservation

Clean coaltechnology(IGCC)

Diversify coalsources

Encouragecogeneration
systemComply withcomprehensive
clean energy
policyFinancialincentives

Apply super
critical units

Tighten emission
permission for Sox,
NOx, and CO2

13煤政策框架煤政策框架背景

国内外煤的形势煤市场的自由化环境保护

中国台北的煤政策

政策指导方针

稳定煤的供应

增加能源效率政策措施

调节煤的储备在
安全数量内

加强节能

煤来源的多样化

采用超临界机组鼓励融资鼓励热电联产

促进环境保护

加强研发

采用综合清洁能源
政策

清洁煤技术
(IGCC)

减少 Sox, NOx,and CO2排放量

14

2006
2006 Coal
Coal Supply
Supply andand Demand
Demand Structure
Structure
2006年煤供应与需求结构
2006年煤供应与需求结构 其他钢铁Iron &
Steel
11.9%

Others
9.7%

From
other
regions
2%

来自其他地区

Total : 62.31
million M.T.

来自亚洲地区
From
Asianregion98%

水泥
Cement4.0%

Total : 61.85
million M.T.

Power
76.7%

电力

Coal Supply

Coal Demand

煤的供应
15

Coal
Coal Supply
Supply andand Demand
Demand Outlook
Outlook煤供应与需求前景
煤供应与需求前景
1,000TCE

SupplyDemand120,000

供应

需求108,700
103,420

100,000
91,95289,36380,00060,00074,60762,31064,18061,8502006

62,9002007

72,45067,532
65,143
2010

2015

2020

2025 Year

16

Conclusions
Conclusions
Coal consumption is expected to increase more
substantially in power generation and other users,
and depends totally on imports.
In 2006, coal use reached 62.2 million M.T. and will
increase to 2025 108.8 million M.T..
Chinese taipei efforts for coal tasks are aimed tostabilize coal supply, enhance energy efficiency,
promote environmental protection, and reinforce R&D
programs.
International cooperation on clean coal technologies
with APEC economies should be enhanced to utilize
coal in more efficient way and more environmental
friendly manners.
17

结论
结论
对于发电部门和其他用户来说,预计煤的需求量将会大大增加,并且全部依赖于进口.
在 2006 年 , 煤的使用量达到 62.2 百万 M.T., 并且预计在 2025
年将会达到108.8百万M.T..
中国台北煤炭工业的主要目标是稳定煤供应、增加能源利
用效率、促进环境保护、以及加强研发项目.
在清洁煤技术方面应加强与 APEC 的国际合作，促进以更加
有效的方式和更加有利于环境的方式使用煤炭资源.

18

谢谢 !

Day 1 Monday 15 October 2007
Session 4: Coal Demand Outlook 2

Speech 5 Japan
Coal Policy of JapanMr. Hiroyuki Kondo
Deputy Director
Coal Division
Agency for Natural Resources and Energy (ANRE)
Ministry of Economy, Trade and Industry (METI)Japan

Hiroyuki Kondo
Deputy Director
Coal Division, Agency for Natural Resources and Energy (ANRE)
Ministry of Economy, Trade and Industry (METI)
Government of Japan
Education:
Apr. 1992 to Mar. 1994
Tokyo Institute of Technology (Master of Engineering)
Apr. 1988 to Mar. 1992
Tokyo Institute of Technology (Bachelor of Engineering)
Career:June 2006

Deputy Director, Coal Division, ANRE, METI

-Present
July 2004 Deputy Director, Medical Device Industry Division, METI
Apr. 1994 joined MITI (*)(*) MITI (Ministry of International Trade and Industry) was reorganized as METI in
2001.

0

APEC Clean Fossil Energy Seminar 2007

Japan’s Coal-Related Policies
October 2007
Hiroyuki Kondo
Coal Division
Agency for Natural Resources and Energy
Ministry of Economy, Trade and Industry
Government of Japan1

Trend of Energy Mix of Japan■Since the two oil crises in the 1970s, Japan has pursued alternative energy
resources. Japan has overcome the increase of energy consumption by the use ofimported coal, LNG and nuclear power.
＜Trend of Japan’s primary energy supply＞
10^18J

hydro, subterranean

25

other energy22.8

23.5

23.1

20.1

9.4%

nuclear

20
16.1

15.3

14.3%

17.0

16.6

LNG

10.2%

15.5%

15 13.4

16.5%

coal

17.0%

20.1%

19.9%

10
71.9%

oil
77.4%

66.1%

50.0%

57.2%

5

0
1970

1973 1975

1980

1985

1990

1995

2001 2003

FY

2

World Hard Coal Trade 2005
 JapanJapanisisthethelargest
largestimporting
importingcountry
countryofofcoal,coal,withwithimports
importsamounting
amountingtotomore
morethanthan178
178Mt
Mtofofcoal,coal,equal
equaltotoone
onequarter
quarterofofworld’s
world’shard
hardcoalcoaltrade.
trade.

21.9Mt

その他欧州
Other Europe
45.0Mt18.5MtOECD欧州OECD Europe
237.0Mt

ポーランド
Poland20.8Mtカザフスタン
Kazakhstan
16.9Mtロシア
Russia78.7Mt19.7Mtカナダ
Canada
27.7Mt10.5Mt

7.8Mt
7.6Mt

51.4Mt中国
China
71.8Mt22.1Mt

6.2Mt
14.2Mt27.8Mt55.4Mt
4.7Mt

アフリカ・中東
Africa & Mid. East
19.2Mtその他アジアOther Asia
227.2Mt
68.4Mt4.0Mt

Source： IEA, “Coal Information 2006”

日本
Japan
177.7Mt

北米
N. America
45.7Mt12.6Mt46.7Mt

8.1Mt

南アフリカ
South Africa
73.0Mt

7.2Mt

29.9Mt102.9Mt

19.5Mt

3.3Mt

OECD欧州OECD Europe
237.0Mt

米国
United States
16.2Mt45.1Mt26.7Mtコロンビア
Colombia
55.5Mt79.6MtインドネシアIndonesia
108.0Mt

4.7Mt

4.2Mt

豪州
Australia
231.3Mt

4.9Mt

南米
Latin America
18.4Mt3Japan’s Coal Imports by Supplier Country and Coal Type●Within Japan’s overall primary energy supply, coal (21%) represents the second most significant energy
source, following oil (49%).
●Imports of fuel coal are increasing by 8.1% annually on average.
●Since the 1990s, imports of fuel coal from China and Indonesia have increased significantly.
●Imports of coking coal have remained almost flat, and dependence on Australia has increased by nearly
10% from the 1980s.
●While imports of coking coal from the U.S. and Canada have decreased, those from Australia and China
have increased.
Changes in imports of fuel coal by country
豪州
Australia（ 百万トン）(Million
tons)

中国
China

ｲﾝﾄﾞﾈｼｱIndonesia

米国
U.S.

カナダ
Canada南アメリカ
South America

ロシア
RussiaChanges in imports of coking coal by country
その他
Others(Million tons)（ 百万トン）

豪州
Australia

カナダ
CanadaIndonesia
ｲﾝﾄﾞﾈｼｱ

China
中国

RussiaロシアSouth America
南アメリカ

U.S.
米国

Others
その他

１００

１００
94.9

９０

94.8

９０

84.9

82.9

81.5
78.7

８０

78.8

８０
73.8

75.2
67.4

７０

７０

68.6

69.7

73.3

73.3

78.1
76.8

73.6
69.0

68.1

70.5

68.8

69.8

71.8

70.2

67.7

69.0

64.9
62.2

６０
55.2

61.7

６０

56.9

５０

48.1

５０
37.0

４０
28.0

３０

30.6

39.5

41.8

４０

32.2
59.0

25.0

２０
１０

19.8
37,2

13,3

17,2

19,0

20,9

21.6

86

87

88

89

90

25,4

24,4

25,8

91

92

93

28,6

32,1

32,1

36,3

39,5

43,2

46,1

48,9

60,2

３０

53,3

２０
29,4

30,6

30,2

86

87

88

34,2

34,2

34,4

36,5

36.0

36.0

89

90

91

92

93

94

46,3

45,1

42,5

42,4

44,5

42,1

00

01

02

03

04

05

40,8

33,2

34,4

36,4

34,0

95

96

97

98

１０

０

０
94

95

(FY)
年度

96

97

98

99

00

01

02

03

04

05

99

(FY)
年度

Note: Data before and after FY2001 is different. These statistics are based on different classifications of coal. The portion of the total coal supply
categorized as fuel coal in the “Annual Report of Energy Production, Supply and Demand Statistics” is included in coking coal in the “Trade
Statistics.” Therefore, imports, in particular those of Indonesian coal, have shown a significant decrease since 2001.
For the purpose of statistical processing, imports from Russia in FY1999 and FY2000 is included in “Others.”
Source: FY2000 and before: “Annual Report of Energy Production, Supply and Demand Statistics” (Ministry of Economy, Trade and Industry)
FY2001 and after: “Trade Statistics” (Ministry of Finance)4Industry-by-Industry Changes in Coal Demand（Million tons)
200
15%
48%

45%

14%
44%

15%

42%

15%
41%

17%
37%

35%

18%

19%

20%
32%

130

34%

20%

20%
29%

32%

20%
27%

20%

21%
25%

23% 21%

22% 21%21%21%

21% 19%22% 19%21% 19%19% 19%126 130 131

OthersPower
Generation

37%

41%

42%

43%

44%

43%

46%

47%

47%

48%

49%

50%

51%

53%

54%

57%

57%

58%

59%

59%

Steel
Production
60%

64%

18% 19%'81 '8263%'80

16% 21%

21%

66% 13%

40

18%

60

71% 11%80

93 98 95 97

106 111103 107

62%

120

119 116 118
114113 115

30%

140

100

140

137

39%

160

18%

161
152 154166

14%

178 176180

20
0'83 '84 '85 '86 '87'88 '89'90 '91 '92 '93'94 '95 '96 '97 '98 '99 '00'01 '02 '03 '04 '05

Fiscal Year
Compiled by the Institute of Energy Economic, Japan
Note: As the Energy Production, Supply and Demand Statistics were abolished in December 2001, figures for FY 2000 and earlier andthose for FY 2001 and thereafter were taken from different sources. Figures for FY 2000 and earlier are based on sales volumes and those for
FY2001 and thereafter are based on delivery volumes.
Source：FY 2000 and earlier—Compiled from annual reports on Energy Production, Supply and Demand Statistics
FY 2001 and thereafter—Compiled from Monthly Reports of the Current Survey of Energy Consumption with regard to demand
for steel production and “others” and from Monthly Reports on Electric Power Statistics with regard to demand for power
generation

5

Trend of Ratio of Japan’s Power Resources
Coal-fired power generations (25%) are one of Japan’s major power resources,
following nuclear power generations (29%) and LNG power generations (26%).
100 M Kwh
億Kwh
10,000

9,705

8,557
1,046

8,000

8,730
1,044

8,950
1,142

9,018
1,156

9,176
1,092

9,396
1,098

9,240
1,079

9,447
1,076

hydroelectric etc

9,355
1,210

水力他
原子力

7,376
1,053
3,165
2,911

6,000

3,021

3,191

3,219

2,949

2,400

2,824

石 炭

3,322
890

798

oil

2,611

2,491

LNG

812
985
1,510

1,391

1,126

868

2,405
1,918

2,037

2,146

594

971

1,951

2,000

石 油
ＬＮＧ

3,198

2,014

4,000

nuclear

1,195

2,479

2,475

2,517

2,221

1,639

719

1,172

1,237

1,345

1,348

1,529

1995

1996

1997

1998

1999

1,894

2,093

2,244

2,397

1,732

2000

2001

2002

2003

2004

coal

0
1990

Compiled by the Institute of Energy Economic, Japan6

Demand for Coal in Asia (by Country)●Consumption of coal is expected to increase from 2.39 billion tons in 2003 to 3.65 billion tons in 2010 (1.5times or 6.2% annually), and to 4.61 billion tons in 2020 (1.9 times or 3.9% annually). 65% and 22% of theincrease will be observed in China and India, respectively.
●China, which had been a supplier country, has become a coal-importing country. The supply-demand
relationship has become tighter due to a significant increase in coal consumption in Asia.
(Million tons)
5,000

Actual consumption

Estimate（100 million tons)

Increase between 2003 and 2020

Others

14.4

4,000

2.22 billion tons

4.8
0.2

0.5

1.3

4%

Japan

Korea

ChineseTaipei Indonesia Others

16%

3,000
China

India

Indonesia

19%

0.1

1.0

4%

Chinese Taipei
South Korea

2,000

Japan

5%
17%

65%
India

70%
15%

1,000

65%

13%

China

66%
68%
0
1980

1990

2000

2010

2020

7

International Cooperation to Ensure a Stable Supply of Coal (1)Collection, analysis and provisionof basic geological and coal deposit
information

Support for domestic private companies

Overseas tectonic examinations
・Implementing tectonic examinations incoal-producing countries where
examinations by private companies are
difficult, in cooperation with thegovernments of these countries
・Entrusting to private companies withthe acquisition of interests andimplementation of detailed
examinations

Examinations of coal deposits

Exploration anddevelopment

Examinations of potential ofdeveloping overseas coal deposits

Exploration anddevelopment ofcoal deposits byprivate companies

・Granting subsidies for two-thirds ofexpenses for Japanese companies toimplement examinations fordeveloping coal deposits in foreigncountries

Financing anddebt guaranteeby the JBIC
Trade insurance
by the NEXI

Examinations for highly-advanced development of overseas coal
Implementing examinations pertaining to infrastructure necessary for understanding of coal supply capability*Corporations above have been conducted by NEDO, JCOAL and others subsidized by METI.

8

International Cooperation to Ensure a Stable Supply of Coal (2)１．Project to Enhance the Coal Industry in CoalProducing Countries

2．Low-Grade Coal Improvement Technology

Japan transfers its coal mine technology in coal-producing
countries, such as China, Indonesia, Viet Nam etc. in orderto ensure stable supply and less accidents in these countries.

Japan is conducting an international cooperation to
improve Indonesian low-grade coal. It aims at
contributing to increase coal supply in Indonesia andother Asia-Pacific countries.
This cooperation has been conducted by JCOAL
subsidized by METI.

3. Oversea Tectonic Examinations
In coal-producing countries (*), Japan is conducting
tectonic examinations with the countries. It also aims at
contributing to increase coal supply in the coal-producing
countries.
These examinations have been conducted by NEDO,JCOAL and others subsided by METI.

・Budget: about 20 billion Yen (FY 2002 to FY 2006)
・Number of trainees: about 1,400 from China, Indonesia andViet Nam (FY 2002 to FY 2006)
・Number of Japanese technicians for coal-producing countries:
about 900 (FY 2002 to FY 2006)
・This project has been conducted by NEDO and JCOAL
subsidized by METI..

(*) Japan has conducted this cooperation so far with
China, Indonesia, Viet Nam, Malaysia and Mongolia.

9Japanese Clean Coal Technologies

10Efforts for Environmentally-Conscious Coal Utilization Technology
Environmentally-Conscious(Clean Coal Technology)● In order to deal with the future expansion of global demand for coal, it is necessary to promote development anddissemination of environmentally-conscious coal utilization technology (Clean Coal Technology: CCT) insecuring a stable coal supply.
Reducing
environmentalload (Reduction ofCO2, etc.)

Potentiality of
new utilization
methods of coal

Resource
constraints

Disposition ofcoal ashTechnology forenhancing efficiency◇Integrated coal gasification fuel cell combined cycle(IGFC)◇Next-generation highly-efficient coal gasification
technology

Technology forconverting to raw
fuels◇Technology for direct coal liquefaction◇Coal flash partial hydropyrolysis technology(ECOPRO)◇Hydrogen producing technology for using coal andrecovering CO2◇Technology for convering catalyst-free coalcarbonization gas

Enhancement ofquality andtechnology for
effective utilization of
low quality coal

◇Technology for upgrading low quality coal (UBC)

Effective utilization ofashless coal and coalash◇Ashless coal technology (Hyper-coal)11Superiority of Japan’s Coal-Fired Power Plants
Japan’s
Coal-Fired
Comparison of heat efficiency of coal-fired power plants by country
Heat
Efficiency
(%)
44

Japan

England/
Ireland

Northern
EuropeFrance

South
Korea

Germany

Australia

U.S.

France

China

India

Japan

Northern Europe

40
EnglandU.S.

36

Australia

32

Germany
China
India

28
24
22

Korea

1990

1992

1994

1996

1998

2000

2002

＊Heat efficiency means heat efficiency at the generating end (Lower heating value basis)
Source：UPDATED COMPARISON OF POWER EFFICIENCY ON GRID LEVEL（2006）（ECOFYS）

12

International Cooperation to Promote Clean use of Coal (3)4. Clean Use of Coal
【 CCT Transfer Training Project】
Japan has accepted trainees from Asia-Pacific countries,
such as China, Indonesia and Thailand in order to promotetransfer and spread of CCT.
About 650 trainees have been accepted (1996-2006)

Example of CCT Model Plant Project:
The Cuo Ong coal preparation plant, Viet Nam【 CCT Promotion Seminar Project】
Japan has held seminars to introduce Japanese original
CCTs to Asia-Pacific countries.
28 seminars have been held (1998-2006)【CCT Model Plant Project】
Japan has constructed and operated CCT model plants in
Asian countries.
28 plants have been constructed (1993-2006)*Projects above have been conducted by NEDO,JCOAL, and others subsidized by METI

13

HP of Prime Minister of Japan and His Cabinet

14

HP of Prime Minister of Japan and His Cabinet

15

1. Innovative Zero-emissions Coal-fired Power Generation○ Coal gasification to power gas turbines, combined with the use of its waste heat to power steam turbines○ Recovery of hydrogen from the gasification process for the use for fuel cells○ CO2 Capture and Storage (CCS) technology to realize zero-emissions coal-fired power generation○ Innovative separation membrane technology to improve the separation rate of CO2 from hydrogen and nitrogen,and halve the CCS cost

Benefits
Zero-emissions Coal-fired Power Generation Plant (FutureGen – USA)Electrictransmission
lines• Coal-fired power generation currently accounts for around 30 %of the global CO2 emissions.
• The efficiency of coal-fired power generation improves from thecurrent 40% to 55 %, and reduces CO2 emissions by around30%.
• CCS, together with the above improvement, realizes zeroemissions coal-fired power generation.

Carbon dioxide injection well

Ongoing International Cooperation

Carbondioxidestorage• FutureGen was proposed by the US Department of Energy in 2003. The US, Japan, India, South
Korea, and China currently participate in the project. This project focuses on the demonstration
experiments of ; the separation system of hydrogen and CO2 from coal, and the undergroundstorage of CO2. The total expenditure on this multilateral cooperation project stands at around
US$1 billion.
• Since 2003 the Research Institute of Innovative Technology for the Earth (RITE) and the US
Department of Energy’s National Energy Technology Laboratory (NETL) have been jointly
engaged in international research on the separation membranes.

Source: the US Department of Energy website

16

Japan’s Integrated Coal Gasification Combined
Cycle (IGCC)• Transmission end
efficiency target: 48%• Reduction of CO2 : 20%• Sep. of FY2007: Initiate
250MW demonstration test
• Consortium: 11 power
corporations• 30% subsidy by METI
• Gasifier : Air blown
17

Japan’s Integrated Coal Gasification Fuel Cell
Combined Cycle (IGFC)• Coal Energy Application forGas, Liquid and Electricity(EAGLE)• Test operation (STEP2): FY
2007～ FY 2009
• Continuous operation
performance: 1,000 hours• CO2 reduction : 30%• Adaptability test for three
types of coal
• Main organization :JPOWER
18

Future Gen Project

The world’s first power plant to• Pioneer advanced hydrogen production from coal
• Emit virtually no air pollutants• Capture and permanently sequester carbon dioxide
Government-Industry Cost-Shared Partnership in a $1Billion
project
・United States initiated this project. China, Korea, India and Japan
contribute this project.
19

Callide Oxyfuel ProjectJapan and Australia are working together about The Callide A project. This project, theworld’s first demonstration of oxy-fuel combustion with CO2 storage will make a significant
contribution to the development of technology that can be retrofitted to power stations tocapture greenhouse fas emissions.

N2

CO2 recovery
systemP.C.
(C, H…)

Boiler

(CO2,
H2O…)

CO2

Air
(N2, O 2)

O2

Air separation
unit(CO2, H2O…)

H2O…

Flue gas recirculation
Features・Direct CO2 recover.
・Higher plant efficiency is expected for CO2 recover.
・Flue gas treatment equipment are small-sized or non-installed.
・NOx and SO2 emissions are reduced greatly.
*In terms of Japan, this project is conducted by JCOAL and others subsidized by METI.

20

Thank you for your kind attention!

21

Day 1 Monday 15 October 2007

Session 5:
Clean Coal Power Generation

Day 1 Monday 15 October 2007
Session 5: Clean Coal Power Generation

Speech 1 PR China
Environmental Protection Technology Status and Development
Orientation in Coal-fired Power Plants

Mr. Wang Zhongqu
Director
Safety and Operation Department
China Guodian Corporation
PR China王忠渠
中国国电集团公司安全生产部主任、高级工程师。1983年毕业于
山东工业大学热能动力专业，2000年获得华北电力大学工学硕士学
位。曾在河北电力试验研究所、河北省电力局和多家大型火电厂长期从事生产技术工作。先后担任河北省电力局科长、河北省西柏坡发电厂厂长助理、河北省衡水发电厂副厂长、河北省邯峰发电厂厂长等职务。2002年调入中国国电集团公司，担任安全生产部副主任、
主任职务。

1

WangZhongqu火电厂的环保技术现状与发展方向Current State and Development of
In 1983, Mr. Wang Zhongqu graduated from Shandong University ofTechnology
of Environmental
Scienceand Technology in Thermal
Power, and in 2000 he obtained
Master’s degree of Science in North China University of Electrics. He has
Protection
inInstitute
ThermalPowerplantsever worked in Hebei
of Electric Power,
Hebei Electric
Power
Agency and several coal-fired power plants engaging in power production
and technology. After serving as Assistant Director of Hebei Xibaipo Power
Plant, Vice Director of Hebei王忠渠Hengshui Power Plant and Director of Hebei
Hanfeng Power Plant, he has acted as vice Director and now Director of
Wang ZHongqu
Department of Safety Management
and Production in China Guodian
Corporation since 2002.

中国国电集团公司CHINA GUODIAN CORPORATION

主要内容
Content
1

2

中国电力发展与能源结构
China Power Development and Energy Structure

国电集团公司的火力发电与环保现状
Thermal Power Generation and Current State ofEnvironmental Protection in GuoDian Corporation

3 火电厂的污染防治技术
Pollution Controlling Technical of Thermal Power plants3

1

中国电力发展与能源结构
China Power Development and Energy Structure• 电力装机总量 total installed generating capacity4

1

中国电力发展与能源结构
China Power Development and Energy Structure• 能源结构 energy structure¾以煤炭为主，约80%的电量来自于煤炭的燃烧
80 percent of generating capacity produced from coal-fired
power plants¾全国的发电装机容量中火电约占75%
The installed capacity of thermal power accounts for 75 percent
of total installed generating capacity¾火电中煤电机组占95%左右
coal-fired units account for 95 percent of thermal power units5

2

国电集团公司的火力发电与环保现状
Thermal Power Generation and Current State ofEnvironmental Protection in GuoDian Corporation
14000
12000
10000
8000
6000
4000
2000
0
2003

2004

装机容量（万千瓦）

2005
发电量（亿千瓦时）2006 年燃煤量（万吨）6

2

国电集团公司的火力发电与环保现状
Thermal Power Generation and Current State ofEnvironmental Protection in GuoDian Corporation• 环保现状 Current State of Environmental Protection¾ 2006年国电集团所有在运机组烟尘排放量为31万吨, SO2排放量127
万吨, NOX排放量69万吨。
Dust emission 310 thousand tons; SO2 1270 thousand tons; NOX 690
thousand tons in 2006
¾ 国电集团公司重视污染治理和发展环保科技产业
Emphasize controlling pollution and developing science andtechnology industry of environmental protection¾ 南京国电环保院的袋式除尘和膜法废水处理技术处于国内领先水平State Power Environmental Protection Research Institute’s bag filter
and membrane technology for waste water treatment gains lead indomestic7燃煤发电机组主要产污环节pollutants producing points of coal-fired generating units83 火电厂的污染防治技术
Pollution Controlling Technical of Thermal Power plants• 大气污染防治 Air pollution control（1）烟气除尘 Dust removal旋转式脉冲喷吹袋式除尘器

固定行喷吹脉冲袋式除尘器Rotary Pulse Spraying Bag Precipitator

Pulse Spraying Bag Precipitators

9

天津第一热电厂布袋除尘工程
bag precipitatorin Tianjin No.1 power plant10运行后的内蒙古丰泰发电公司布袋除尘器效果
bag precipitator in FengTai power company, Innermongolia11 低压脉冲旋转喷吹袋式除尘器与固定行喷吹袋式除尘器的比较技术比较

旋转喷吹袋式除尘器

固定行喷吹脉冲袋式除尘器

特点

只用一个大尺寸的低压脉冲阀，连接一组旋转臂作喷吹管，一边旋转一边对花板下滤袋进行喷吹清灰每个脉冲阀出口安装喷吹管，喷吹孔（通常有十几个）对准滤袋进行高效脉冲喷吹
清灰。喷吹管用锁紧装置固定在花板上方
的除尘器壳体上优点在线或离线的高效均匀清灰系统；高、中模块式结构，可设计在线或离 或低压选择；压缩空气喷射引流保证滤袋线清灰；脉冲阀数量少底部清灰压力；结构简单；造价、运行费
用低；具有大量国内外业绩缺点结构复杂，安装和加工要求严 脉冲阀数量较多结构旋转臂会产生磨损现象，
须定时维护
12

3 火电厂的污染防治技术
Pollution Controlling Technical of Thermal Power plants• 大气污染防治 air pollution control（2）烟气脱硫 Flue Gas Desulphurization, FGD¾脱硫工艺 FGD Processes
9燃烧前脱硫 desulphurization before combustion
9燃烧中脱硫 desulphurization during combustion
9燃烧后脱硫 desulphurization after combustion¾应用情况 application
9国电集团龙源环保公司湿法烟气脱硫LongYuan Environmental Engineering Company’s Wet FGD
13阳宗海电厂脱硫工程
FGD engineering of YangZongHai power plant, Yunnan

14天津一热脱硫工程
FGD engineering of Tianjin No.1 power plant15华电贵州清镇电厂脱硫工程
FGD engineering of Qingzhen power plant, Guizhou

16

3 火电厂的污染防治技术
Pollution Controlling Technical of Thermal Power plants• 烟气脱硫技术展望 the prospect of FGD
9 脱硫脱硝一体化集成技术
de-SOX and de-NOX integration
9 烟气脱硫装置的节能化、小型化和提效研究energy-saving, miniaturization, efficiency- improving
9 脱硫副产物的资源化利用
comprehensive utilization of FGD by-product17

3 火电厂的污染防治技术
Pollution Controlling Technical of Thermal Power plants• 大气污染防治 air pollution control（3）低氮燃烧与烟气脱硝¾技术类型 technique type
9低NOX燃烧技术 Low-NOX combustion technology
9烟气脱硝 Flue Gas Denitrification¾应用情况 application
9国电铜陵电厂600MW机组烟气脱硝工程
GuoDian Corporation Tong Lin power plant’s Flue Gas
Denitrification engineering18

3 火电厂的污染防治技术
Pollution Controlling Technical of Thermal Power plants• 水污染防治 water pollution control
9常规电厂废水处理
conventional waste water treatment
9中水回用与海水淡化工艺
reclaimed water reuse and seawater desalination
9石灰深度处理法 lime treatment
9微/超滤膜技术
micro-filtration/ Ultra-filtration19

膜过滤深度处理主要工艺流程Process flow of membrane filtration advanced treatment20

膜法深度处理工艺与传统石灰石处理工艺比较比较内容传统石灰石处理工艺

生化处理+超滤膜过滤工艺

系统可靠性

较成熟

国外成熟，国内开始应用

自动化程度

一般

较高

基建投资

中等

投资高

占地面积

较大

较小

运行费用

中等

较低

维护工作量

劳动强度大

维护工作量小运行稳定后出水水质好
SDI：3~5，浊度≤3 NTU

膜阻挡层可靠，出水水质好SDI≤3，浊度≤0.5 NTU以下

出水水质

出水水质
应用领域

易腐蚀结垢，浓缩倍率低 浓缩倍率可控，防垢防腐较易
中水深度处理中水回用深度处理，海水淡化预处理21传统石灰石处理工艺与膜处理工艺投资运行费用比较（以2×300MW机组为例）
石灰深度处理工艺

膜法深度处理
工艺

空冷

湿冷

空冷

湿冷

处理水量
（吨/天）

11000

40000 11000

40000

工程静态投资
（万元）

1500

3100

7000

内容

2900

备注

膜法工艺中考虑了前加曝气生
物滤池单元

年运行费用
（万元/年）

320205

含水电、药剂和设备折旧费，
膜法工艺含膜柱更换费用吨水造价（万元/吨水）

1.7—2.2

2.5—4.0

根据系统配置要求不同，会有
较大差异

运行成本
（元/吨水）

0.82左右0.51左右不含人工费
22

3 火电厂的污染防治技术
Pollution Controlling Technical of Thermal Power plants• 膜法深度处理工艺应用情况
application for membrane filtration advanced treatment
处理水量

总投资

经济效益

太原第一热电厂生活污水及工业废水深度处理工程1500吨/日

2900万元 626万元/年

内蒙古东胜热电厂
2×330MW空冷供热机组新建工程污水深度处理站工程

11000吨/日

2500万元 1200万元

天津大港油田污水膜法深度
处理工程34800吨/日23

太原第一热电厂水处理工程24
Water Treatment Engineering of Taiyuan No.1 power plant天津一热水处理工程Water Treatment Engineering of Tianjin No.1 power plant25

谢 谢！
Thanks26

Day 1 Monday 15 October 2007
Session 5: Clean Coal Power Generation

Speech 2 PR China
Energy Saving of Coal-fired Power Plant

Mr. Jin Donglai
Deputy Director
Safe and Operation Department
China Power Investment Corporation
PR China

JinDonglai
In 1982, Mr. JinDonglai, currently a senior engineer, graduated from North China Institute of Electrics as a Master of
Science in the major of thermal power kinetic. From 1982-1984, he acted as teaching assistant in NCIE. From 1992-1998, heworked in the Department of Safety Supervision and Production in the Ministry of Electrics and the Department of Electrics
under the Ministry of Energy. From 1998 to 2002, he was Vice Director and Director in the Power Transmission Operation
Department of the State Grid. From 2003 to 2005, he was Vice Manager of the Department of Safety & Production in
China’s Electrics Investment Co. From 2005 to 2007, he served as Vice General Manager in the Jiangxi Branch of CEIC andfrom 2007 to present, he has been acting as the Vice Manager of the Dept. of Safety in CEIC.
His primary interest of research includes overseas studies of electrics, Safety Management in power plant and the CPC’s rolein Technology Management and Production.
Awards: Mr. JinDonglai was the third prize winner of ’98 Science and Technology Award given out by Ministry of Energy
for the research project entitled “Testing Characterizations of Two Dimensional Corona Field and Its Applications”. In 1991,
he won the third prize of such an award again for studies on nuclear and coal sourced power generation. In 1996, he won thesecond prize of Science and Technology Award given out by Ministry of Electrics for a project related to the upgrading andmodernization of coal-fired power generation sets. From 1999 to 2000, he presided over the revision and formulation of“Twenty-five Key Requirements for the Prevention of Severe Accidents in Electric Power Generation”. From 2001-2002, hepresided over the formulation of the State-level “Principles to the Overhaul of Equipments in Electricity GeneratingEnterprises”, officially carried out on 1st June, 2003.
In 2006, he won the second prize of Science and Technology Award given out by CEIC for “The Application of A New
Model of Internal Counter Flow Nozzle Button on 150MW Atmospheric Circulating Fluidized-bed Units”.

Energy-saving Technologies ofThermal Power Plants
Jin Donglai
China Power Investment Corporation
15 October 2007

Foreword
In 2006 China's total electricity generation is 2834.4TWh,including 2357.3TWh of thermal power, which accounted
for 83% of the country's total electricity generation, and416.7TWh of hydropower, 14.7% of the country 's total
electricity generation. In recent years, thermal power
generation has been developing rapidly with an annual
growth rate of about 15%. By the end of 2006, the country's
total installed generating capacity reached 622 GW, with
484 GW of thermal-power capacity which accounts for
77.82% of nation’s total capacity and 129 GW ofhydropower with a ratio of 20.67%.

Foreword
China's total installed generating capacity and total
electricity generation are both ranking the second in theworld, and maintaining a relatively high growth rate inthese years. In the next five to ten years, the ratio ofChina's installed generating capacity of thermal power
will remain high.

Foreword
Although China's energy reserves are rich, but per capita
availability of energy resources is low. China's fossil energy
reserves exploitable are proven to be more than 823 billion
tons of standard coal. And remaining economic recoverable
reserves is of 139.2 billion tons of standard coal which
accounts for 10% of the total world's energy resources andproven coal resources, amount to 687.2 billion tons, which
are ranking the third in the world. And the direct use ofproven raw coal reserves is 188.6 billion tons. But it is only
about 50% of the world per capita average. Oil and natural
gas reserve per capita is lower than the world average.

Foreword
China is the world's second largest energy producer andconsumer. Energy consumption mainly relies on domestic
supply and energy self-sufficiency rate is 90%. In 2006,
China's raw coal production is 2.37 billion tons; crude oil
production 0.184 billion tons; natural gas production 58.55
billion cubic meters. Raw Coal consumption is 2.3 billion
tons, of which, 1.142 billion tons are burned by thermal
power units with a capacity of 6000kW and above, which
accounts for 48.19% of the total coal consumption.

Foreword
According to the current coal mining and utilization, thecoal reserves in China can only be used for less than 100
years, therefore, China's coal resource exploitation andsustainable use are facing serious problems.

Foreword
In the Proposals on the 11th Five-year Plan for National Economic andSocial Development Plan, it is clear that the conservation of resources isthe country’s basic policy. Our country’s energy-saving guidelines are“developing a scientific development concept as a guide, adhere to theprinciple of energy conservation priority, changing the mode of growth,
adjusting structure of economy, accelerating technological progress as
fundamental, improving law systems and using energy efficiently topromote the sustainable economic and social development. Our country
will put energy-saving and consumption reduction as the importantwork ahead and our goal is to reduce 20% of unit GDP energy
consumption in the period of "11th Five-Year Plan".

Foreword
According to the statistics of thermal power generation in
2006, net coal consumption rate of thermal power
generation is 366 g/kWh, which is 30 g/kWh higher than
the average level in developed countries, about additional
67 million tons of standard coal or nearly 100 million tonsof raw coal every year will be burned. As thermal powerindustry providing secondary energy for the society,improving the utilization efficiency of coal, promoting
energy-saving and consumption reduction vigorously andextending coal consumption time are important tasks
ahead.

Status Of Energy Consumption And Analysis(1) The status of thermal power energy consumption
Since the beginning of the 21st century, the nation’s technology andequipment of thermal power plants has developed quite rapidly.
Supercritical and ultra-supercritical thermal power generating units
have been put into operation in succession. Large capacity, highefficiency and environment-friendly generating units are gradually
becoming the main stream. According to the preliminary statistics, 62
generating units with a capacity of 600 MW each and 349 generating
units with a capacity of 300MW each were put into operation in China
in 2005 alone. However, 200 MW，125MW and even lower capacity
units still account for about 40% of total thermal power generating
capacity. The average capacity of thermal power generating units isonly 98MW in 2005.

Status Of Energy Consumption And Analysis
According to the statistics, in 2006 China's net coal consumption rate ofthermal power plant is 366 g/kWh. But in some developed countries, it
is only 335 g/kWh. That means producing every 1kWh of electricity willconsume about 31 grams of standard coal in China more thandeveloped countries. According to the statistics of 2006 thermal power
generation, China consumed more than 67 million tons of standard coaljust in that year. Contrast to the developed countries such as Japan (299g/kWh), South Korea (300 g/kWh), Italy (303 g/kWh), the net coalconsumption rate was about 60 g/kWh higher in China, more than 130
million tons of standard coal a year will be wasted.

Status Of Energy Consumption And Analysis
In different types of units, there are obvious gaps between our country
and the developed countries. For instance:ultra-supercritical power units with a capacity of 600 MW and above,
the net coal consumption rate is 290-300 g/kWh, 5-10 g/kWh higher
than the developed countries;
supercritical thermal power units with a capacity of 600 MW andabove, net coal consumption rate is 310-320 g/kWh, 10-15 g/kWh higher
than the developed countries;sub-critical power units with a capacity of 300-600 MW, the net coalconsumption rate is 330-340 g/kWh, 15 g/kWh higher compared withthe advanced level;for 200 MW and below units, the net coal consumption rate is 370-390
g/kWh, 35-60 g/kWh higher compared with the advanced level and 20%
to 40% higher than large capacity units.

Status Of Energy Consumption And Analysis(2) The main reasons for high energy consumption of thermal power
unitsPerformance of main equipment of thermal power plants can notreach the design standard
The main power equipment design level of China's early 200MW, 300
MW thermal power generating units is not high, and it lacked thenecessary testing and optimization. In addition, there are wide gaps
between our country and the developed countries in material and the
manufacturing process. These all caused the result that main equipment
cannot perform design specifications.

Status Of Energy Consumption And Analysis
System design can not attain optimization
First, major auxiliary equipment such as mill, delivery motor andblower lack optimization, thus inadequate or excessive output often
happens.
Second, thermal power system and air system design are usually
unreasonable, resulting in increased energy loss.
Third, new technologies are not used widely.

Status Of Energy Consumption And Analysis
The level of economic operation is not highFirst, electric dispatch is not scientific and economic.
Second, some operators are lack of operation skill and experiences,
furthermore, equipment reliability is poor, so optimization andadjustment are difficult.
Third, fuel price and quality changes frequently, and boiler systemhave some serious leakage, which lead to difficult adjustment.

Status Of Energy Consumption And Analysis
Fuel supply is unstable
One of the biggest barriers which affect the domestic boiler combustionand energy consumption is unstable fuel supply. Due to the differences
between the design coal and the actual coal used, the condition of boiler
combustion deteriorates. As a result, the chance of boiler coking evenflameout increases. Meanwhile, problems such as wear of boiler,
equipment reliability reducing and increasing of energy consumption
appear.

Status Of Energy Consumption And Analysis
Some problems occur in new units
In past few years, more and more power units are under construction,
as a result, design company, manufacturing company and construction
company are in high-load. Such condition affects the design
optimization and the quality of manufacturing and installation. Whilethe units are put into operation, they cannot reach the designed target
and meet such severe problems as abnormal turbine flow installation
space, shaft seal leaking, poor vacuum tightness and low cylinder
efficiency.

Status Of Energy Consumption And Analysis
There are gaps in management
First, energy-saving mainly relies on administrative orders or theletters of responsibility signed by government and enterprises, thatlacks of legal and market means.
Second, individual enterprises are short of sufficient energy-saving
awareness. They do not put energy conservation into an important
position.
Third, the intensity of energy-saving examine is not enough, and theatmosphere of full participation has not been formed.

Main Energy Saving Strategies Of China
Although the thermal energy consumption indicators in our country aremuch higher than the world advanced level, but by strengthening
conservation and the legal system, changing the management philosophy,
upgrading and restructuring the implementation of thermal power
technology, using the advanced energy saving technology and perfecting
the policies to support and enhancing the management of energy-saving,energy consumption indicators of power units in China must be
remarkably reduced.

Main Energy Saving Strategies Of China(1) Adjusting the structure of electricity industry and developing
advanced technology units.
First, we should focus on the development of 600 MW and above thesupercritical units which are more high-efficiency, energy-saving andenvironmentally friendly. These units have the capacity of 600-1000 MW,
the main steam pressure of 25.0 - 30.0MPa, and the temperaturereaching 569-615°C. Super-heater and re-heater use P92, P125, C91
refractory steel pipe; Boiler efficiency is 93% -94%; Turbine uses
advanced design techniques; Blades have the efficient use of the entire
3D design; Turbine thermal efficiency reached 43%-47% and coalconsumption is 280-310 g/kWh.

Main Energy Saving Strategies Of China
Second, we strengthen the work of "developing large units and stopping
small units " and speed up shutting down small thermal power
generating units. 125MW and smaller units follow the implementation ofsubstituting by large units. In the same load level, large units can save
30% to 50% amount of coal. At the end of the "11th Five-Year Plan",our country will shut down more than 50,000 MW small coal-fired units.
Third, we must energetically develop new energy and recycle energy
generation. Such as nuclear power, solar power, hydropower, wind
power, and so on. We shall gradually increase the generation ratio ofclean energy.

Main Energy Saving Strategies Of China(2) Implementing modernizing modification of the turbine system and improving
turbine efficiency.
First, we should strengthen the work of equipment modification especially in 200
MW and 300 MW turbine power unit flow modification, this is an effective
measure of reducing energy consumption. Due to the design and manufacture
limitations, generating units put into operation before the 1990s usually have theproblems of timeworn turbine blade, inefficient cylinder, poor adaptability forvariable load and high heat consumption. Nowadays the application of advanced
three-dimensional blade technology and advanced processing technology can
reduce the blade loss effectively and improve the steam engine's efficiency. Afterthe modification, 200 MW and 300 MW steam turbine units can improve theefficiency of high pressure cylinder by 3-6%, middle pressure cylinder by 2-3%
and low pressure cylinder by 6-10%. At the same time the net coal consumption
rate can reduce 10-15 g/kWh.

Main Energy Saving Strategies Of China
Second, we should implement the modification of the steam heating
system mainly including main steam seal optimization and theredundant thermal system simplification.
Third, we should improve the condenser and cooling water system
including optimizing the design of the condenser pipe structure andlayout; using titanium or stainless steel tube instead of the traditional
pipe; changing the structure and stuffing of the core of cooling tower.

Main Energy Saving Strategies Of China(3) Implementing modification of variable frequency adjusting for large
motors and reducing service power consumption rate.
Excluding the pulverizing system, main rotation auxiliary equipment
such as pumps and fans consume about 50-70% of service power
consumption in a power plant. Since the peak-load operations of apower unit are more frequently, the running time of pumps and fans in
low load condition increases, the system has more energy loss and lower
efficiency. So now modification of variable frequency adjusting method
has been introduced. On the basis of no-changing the original structureof pumps and fans, we install a high-voltage converter on them toachieve speed adjustment which can save 20% to 35% of energy.

Main Energy Saving Strategies Of China(4) Reducing boiler heat loss and improving boiler efficiency.
First, modify burner of boiler in order to gain more adaptability andadjustability, which can prevent coking characteristic and lower non-oil
stable combustion characteristics.
Second, modify soot-blowing system of boiler and ensure the normal
operation in order to improve heat transfer effect of heating surface.
Third, modify Rotary air pre-heater especially which’s leakage rate ismore than 20% to reduce air leakage rate of the boiler. Change thesealing system to dual-seals technology and increase heat transfer
sections from 24 to 48, thus air leakage rate can reduce 5-7%.

Main Energy Saving Strategies Of China(5)Using non-oil (less oil) ignition technology and reducing fuelconsumption.
Plasma oil-free ignition has a very successful application in China andhas achieved obvious results. The theory of plasma oil-free ignition isthat working gas is ionized when it flow through between the cathodeand anode voltage field. The plasma arc which’s temperature reachedthousands of degrees, forms plasma torch and is injected into an air duct.
When the air heats the coal, coal particles are immediately ignited.
Currently researchers have developed a new technology which is called"high temperature air" oil-free ignition. It can consecutively produce
high-temperature air up to 1,000°C after power input for more than 3minutes and ignite air and coal. In addition, several domestic less oil
ignition technologies have gain fairly well effects and make a significant
contribution to oil conservation in electric fields.

Main Energy Saving Strategies Of China(6) Using optimization technology and improving power generating equipment
operating parameters and economic indicators.
First, equip with surveillance information system (SIS). In practical, workableprinciples, combined with comprehensive optimization results of the trials, make
optimum operation of the power generating equipment, running curves andoperating parameters. Help operating personnel to operate and optimize energyloss analysis including the main parameters such as the main steam pressure, themain steam temperature, re-heater temperature, flue gas temperature, flue gas
oxygen content ,pump service power consumption rate, fly ash carbon content ,the service power consumption rate, vacuum, efficiency of high-pressure
cylinder, efficiency of middle-pressure cylinder, ultimately water temperature,
the temperature difference of heaters, super-heater desuperheating water flow,
re-heater desuperheating water flow.

Main Energy Saving Strategies Of China
Second, implement optimal load distribution in the power
units. achieve optimum plant coal consumption targets
according to he best unit load distribution in thecircumstances of certain load.
Third, the 200 MW units should equip with real-time
management optimization system.

Main Energy Saving Strategies Of China(7)Researching and using desulfurization equipment power-saving
technology to reduce the energy consumption of desulfurizationequipment.
First, according to coal providing condition, implement coal blending
measures to maintain the sulfur stability of the coal into the furnace.
Second, according to unit load and the sulfur content, readjusting andoptimizing the operation mode of recycle slurry pump.
Third, take effective soot blowing measures to prevent GGH jam andmaintain desulfurization system in low pressure loss.
Fourth, improve the quality of limestone.

Concluding Remarks
Through large-scale construction of 600 MW and above large-capacity
supercritical units which are efficient, energy-saving and environmentfriendly; implementing "developing large units and shutting down small
units " policy and shutting down small thermal power units; using
energy-saving technological innovation to modify 200MW and above theunits; fulfilling the various measures of economic operation, ourcountry’s energy consumption indicators will be significantly improved.
In 2010, the net coal consumption rate of 300 MW capacity and above
thermal power units in China will be close to the advanced international
level and contribute to the objectives of the "11th Five-Year Plan" by
20% reduction of unit GDP energy consumption.

Thanks

Day 1 Monday 15 October 2007
Session 5: Clean Coal Power Generation

Speech 3 PR China
Promotion of Energy Conservation and Consumption Reduction in
Coal-fired Power Plant with Preserved Efforts in Adopting Advanced
and Higher Parameter Units

Mr. Liu Guoyue
Deputy Manager General
Huaneng Power International Inc
PR China

Adhere to High Starting-Point and High Parameter
Development and Drive Thermal Power Plant to
Save Energy and Reduce Consumption

Huaneng Power International, Inc.
Liu Guoyue

Zhao Ping

October 2007

2007-10-23

I. Adopted performance-advanced high efficiency imported
units and large capacity and high parameter units
1. Constructed and operated 350MW subcritical units for the first time•

In 1984, Huaneng International Power Development Corporation wasestablished and the supporting projects were: Dalian, Shangan,
Nantong and Fuzhou projects.

•

Dalian and Fuzhou respectively introduced two Japanese Mitsubishi
350MW subcritical units•

Shangan and Nantong respectively introduced two American GE
350MW subcritical units.
2007-10-23

1. Constructed and operated 350MW subcritical units forthe first time (cont’d)
Coal consumption for power supply by Dalian, Fuzhou, Nantong andShangan in the year when they were put into operation was 341, 431,
455 and 450g/kWh respectively. By 1995 when the incorporation wasestablished, coal consumption for power supply by the four power
plants was 321, 323, 324 and 334g/kWh respectively and auxiliary
power rate was 3.85, 4.24, 3.85 and 5.01% respectively.

2007-10-23

1. Constructed and operated 350MW subcritical units forthe first time (cont’d)Dalian Power Plant:•

Units 1&2 are manufactured by Japanese Mitsubishi Heavy Industries Ltd•

Unit 1 was put into commercial operation on September 20, 1988 and Unit 2 was put
into commercial operation on January 27, 1989.

•

Coal consumption for power supply in 1988: 314g/kWh, auxiliary power rate 6.12%;•

Coal consumption for power supply in 1995: 321g/kWh, auxiliary power rate 3.85%;•

Coal consumption for power supply in 2006: 323g/kWh, auxiliary power rate 3.61%.

2007-10-23

1. Constructed and operated 350MW subcritical units forthe first time (cont’d)Fuzhou Power Plant:•

Units 1&2 are manufactured by Japanese Mitsubishi Heavy Industries Ltd•

Unit 1 was put into commercial operation on November 17, 1988 and Unit 2 was put
into commercial operation on January 17, 1989.

•

Coal consumption for power supply in 1988: 431g/kWh, auxiliary power rate 7.1%;•

Coal consumption for power supply in 1995: 323g/kWh, auxiliary power rate 4.24%;•

Coal consumption for power supply in 2006: 325g/kWh, auxiliary power rate 3.61%.

2007-10-23

1. Constructed and operated 350MW subcritical units forthe first time (cont’d)Nantong Power Plant:•

Units 1&2 boilers are manufactured by Canadian BW and turbines are manufactured
by American GE•

Unit 1 was put into commercial operation on September 8, 1989 and Unit 2 was put
into commercial operation on April 1, 1990;•

Coal consumption for power supply in 1989: 455g/kWh, auxiliary power rate 6.63%;•

Coal consumption for power supply in 1995: 324g/kWh, auxiliary power rate 3.85%;•

Coal consumption for power supply in 2006: 329g/kWh, auxiliary power rate 3.52%.

2007-10-23

1. Constructed and operated 350MW subcritical units forthe first time (cont’d)Shangan Power Plant:•

Units 1&2 boilers are manufactured by Canadian BW and turbines are manufactured byAmerican GE•

Unit 1 was put into commercial operation on August 12, 1990 and Unit 2 was put into
commercial operation on December 5, 1990;•

Coal consumption for power supply in 1990: 450g/kWh, auxiliary power rate 4.12%;•

Coal consumption for power supply in 1995: 334g/kWh, auxiliary power rate 5.01%;•

Coal consumption for power supply in 2006: 334g/kWh, auxiliary power rate 3.48%.

2007-10-23

1. Constructed and operated 350MW subcritical units forthe first time (cont’d)••

In 1995, the total coal consumption for power supply of the four power plants
including Dalian, Fuzhou, Nantong and Shangan power plants under Huaneng Inc.
was 325g/kWh and auxiliary power rate was 4.16%.
The total coal consumption for power supply by the 11 power plants managed by
Huaneng Power International Inc. was 331g/kWh and auxiliary power rate was
5.5%, far lower than the national average value of 412g/kWh for coal consumption
for power supply and 7.95% auxiliary power rate for thermal power units.
1995年

Coal consumption for
power supply

Auxiliary power rate

Four power plants under Huaneng Inc.

325

4.16

Eleven power plants managed by
Huaneng Power International Inc.

331

5.5

National average

412

7.95
2007-10-23

2. Introduced the 600MW supercritical units and a groupof high efficiency and environmentally friendly units forthe first time
Shanghai Shidongkou No.2 Power Plant:•

Units 1&2 are manufactured by CE-Sulzer and ABB•

Unit 1 was put into commercial operation on June 12, 1992 and Unit 2 was put into
commercial operation on December 26, 1992;•

Coal consumption for power supply in 1992: 333g/kWh, auxiliary power rate 4.95%;•

Coal consumption for power supply in 1995: 314g/kWh, auxiliary power rate 4.11%;•

Coal consumption for power supply in 2006: 308g/kWh, auxiliary power rate 3.35%.

2007-10-23

2. Introduced the 600MW supercritical units and a groupof high efficiency and environmentally friendly units forthe first time
Huaneng Nanjing Power Plant:•

Units 1&2 are manufactured by Russian Taganrog and Ukrainian Kharkov Co.

•

Unit 1 was put into commercial operation on March 17, 1994 and Unit 2 was put into
commercial operation on October 20, 1994;•

Coal consumption for power supply in 1994: 398g/kWh, auxiliary power rate 6.65%;•

Coal consumption for power supply in 1995: 345g/kWh, auxiliary power rate 5.76%;•

Coal consumption for power supply in 2006: 328.6g/kWh, auxiliary power rate 4.93%.

2007-10-23

3. Developed large sized generating units and eliminatedsome background units•

In 1995 when Huaneng Power International Inc. was established, the total installedcapacity of units was 9,050MW, 98% of which was imported units.

•

After reformation of the electric power system, it successfully purchased some power
plant units such as Dezhou, Weihai and Jining in Shandong Province and Shanghai
Shidongkou No.1 Power Plant and accelerated the commencement and construction
and operation of new projects and put into operation some 600MW and 1000MW
domestic made supercritical units such as Huaneng Qinbei, Taicang and Yuhuan.

•

By the end of 2006, the total installed capacity of Huaneng Inc. reached 39,770MW.

2007-10-23

3. Developed large sized generating units and eliminatedsome background units•

Of the 115 managed units, 91 are 300MW and above, being 94% of the total
installed capacity of the company. The capacity of the units 600MW andabove is 12,920MW, 32%; and the capacity of the units 300MW is 24,420MW,61%; and the capacity of the units 200MW and below is 2,430MW, 6%.

•

At the end of 2006, the company eliminated some high-energy-consumption
small units less than 100MW in Shantou Gas Turbine, Chongqing Gas Turbine,
Jining and Xihua.

2007-10-23

II. Strengthened operation management, implemented
equipment modification and reduced unit energy consumption
1. Strengthened equipment operation management and reduced energy consumption.
Since its Phase I units were put into operation in 1988, Huaneng Dalian Power Plant has drawn
on international advanced power plant operation management model and experience andcontinuously implemented mechanism innovation, management innovation and technicalinnovation. In 1994, Huaneng Dalian Power Plant was nominated as the first “First Class
Thermal Power Plant” in China’s electric power industry, symbolizing the company’s operation
management and energy consumption are in the domestic advanced level.
In 1998, Dalian Power Plant put into Phase II 2x350MW subcritical units in 1998. In 2006, its
comprehensive coal consumption for power supply was 320.9g/kWh and comprehensive
auxiliary power rate was 3.89% and energy consumption level was maintained synchronouswith the international advanced level. Unit 3 created a new record of 712d continuous safe
operation.
2007-10-23

2. Paid attention to equipment treatment and modification and controlled unit
energy consumption indices.
Huaneng Nanjing Power plant units are two Russian supplied 300MW supercritical units anddue to reasons of equipment and associated devices, coal consumption was relatively highwhen the units were put into production in 1994. Since then Nanjing Power Plant hascontinuously carried out technical innovation for the units, especially for the unit vacuum
system, water and steam system valves, reheater, high and medium pressure turbine heating
system, deaerator steam exhaust, boiler ignition program control system, soot blower andboiler air preheater sealing devices. Through technical innovation, coal consumption for
power supply dropped from 398g/kWh in the initial operation period in 1994 to 329g/kWh in
2006, 20% down, and reached the advanced level of the same unit types both at home andabroad.

2007-10-23

3. Carried out large scaled technical innovation and reduced unit energy
consumption indices.
Through indicator standard-matching management, Huaneng Inc. carried out through-flow
innovation for the domestic made 300MW units put into operation in early stages. For
example, eight 300MW domestic made units in Dezhou and Shidongkou No.1 Plant were
put into operation at the beginning of 1990s, but due to low unit efficiency, coalconsumption for power supply exceeded 350g/kWh. After 2003, the above four units were
innovated for through-flow respectively and turbine rotors were replaced. In 2006, coalconsumption for power supply was 340.0 and 340.9g/kWh respectively for Dezhou Unit 1
and Unit 2 and 348.7 and 352.3g/kWh for Shidongkou No.1 Plant Unit 1 and Unit 2,
5.8~11.6g/kWh lower.

2007-10-23

4. Actively applied new technology and strengthened energy saving technology innovation.
Since 2002, Fuzhou Power Plant has organized and carried out several energy saving technology innovations,such as boiler air preheater seal innovation, boiler electrostatic precipitator innovation, boiler fuel air andauxiliary air damper control innovation etc. In 2006, in creating energy saving and environmental protection
demonstration power plant, technical innovation force was further expanded and totally 216 various
management and technical improvement projects were carried out, including 21 significant technicalinnovation projects. The successful completion of low investment, quick effect and easy implementation
bottom ash dewatering innovation made positive contributions for Fuzhou Power Plant to comprehensively
complete the auxiliary power rate, fresh water consumption and environmental protection indices for anenergy saving and environmentally friendly demonstration power plant. In 2006 coal consumption for power
plant and auxiliary power rate for Fuzhou Power Plant reached 317.2g/kWh and 3.5% respectively, 1.0g/kWh
and 0.04% lower than the same period of the previous year. In 2007, its energy saving technology innovation
effect was more apparent and in the first half of the year, coal consumption for power supply and auxiliary
power rate rached 311.1g/kWh and 3.12% respectively, 10.2g/kWh and 0.55% lower than the same period of
the previous year.

2007-10-23

III. Took the lead in constructing and operating localized
supercritical 600MW and ultra-supercritical 1000MW units
1. Took the lead in constructing and operating the first supercritical 600MW
high efficiency unit in China.
Huaneng proposed to construct the first domestic made 600MW class supercritical unit
support project in China-Huaneng Qinbei Power Plant, designed unit heat consumption
7,522kJ/kWh, boiler efficiency 93.3%, standard coal consumption for power generation
282g/kWh and coal consumption for power supply 297g/kWh. The two units of Qinbei
Power Plant were both put into operation at the end of 2004 with high speed, high quality
and high performance. At unit load rate 78% in 2006, coal consumption for power supply
for Units 1 and 2 reached 313 and 309g/kWh and auxiliary power rate reached 4.63 and4.44% respectively, symbolizing that the first 600MW supercritical coal fired unit
domesticization demonstration project in China made a perfect success.
2007-10-23

2. Took the lead in constructing the first domestic made ultra-supercritical 1000MW
high efficiency environmentally friendly unit in China
The first ultra-supercritical unit in Huaneng Yuhuan Power Plant 1,000MW Coal Fired Unit Projectis a national key project and its Unit 1 was put into operation on November 28, 2006. After
performance verification test, Yuhuan Power Plant Units 1&2 reached the designed requirementsin performance. Presently the units operate stably and coal consumption for power supply reaches
the best level in the Huaneng Corporation. Coal consumption for power supply in July 2007
reached 298g/kWh and the plant made a outstanding contribution for the corporation’s energy
saving and consumption reduction.
The facilities associated for the main machines such as FGD, low nitrogen burner, high efficiency
ESP and seawater desalination enable Yuhuan Power Plant to become a coal fired power plant withleast coal consumption for each kWh, lowest emission of pollutants, lowest production ofgreenhouse gases and least consumption of fresh water.

2007-10-23

Conclusion ：In the new situation of creating a energy saving andenvironmentally friendly society, Huaneng PowerInternational Inc. pays more attention to energy saving
technology development and advanced management andinvests more manpower and material resources to makegreater contributions for energy saving and consumption
reduction and environmental protection.

2007-10-23

Day 2 Tuesday 16 October 2007

Session 6:
Coal Supply Outlook

Day 2 Tuesday 16 October 2007
Session 6: Coal Supply Outlook

Speech 1 PR China
Coal Demand and Supply and Policy of Coal Industry in China

Ms. Lu Xiaoyan
Director
Research and Consultation
Information Center
China Coal Sales and Transportation Association (CCSTSA)PR China
AuthorMr. Hao Xiangbin
Deputy-General
Information Center
China Coal Sales and Transportation Association (CCSTSA)卢晓燕
中国煤炭运销协会信息中心研究咨询部部长，北京化工大学管理学硕士，《中国煤炭市场(月刊）》副总编、执行主编，《中国煤炭供需产业分析月报》编撰组副组长，从事煤炭产业及煤炭市场分析与研究工作，先后在中国煤炭需求分析与预测、中国能源预测预警系统
研究与建设、2005-2050年中国煤炭需求等重大课题研究工作中担任
工作组组长。

中国煤炭需求、煤炭供
需形势及煤炭产业政策中国煤炭运销协会信息中心副主任
郝向斌中国煤炭运销协会信息中心研究咨询部部长 卢晓燕
2007年10月16日

※中国政府の要望により、本プレゼン資料は非公表

Day 2 Tuesday 16 October 2007
Session 6: Coal Supply Outlook

Speech 2 Australia
Coal Supply Outlook in Australia

Ms. Louis Tamaschke
Assistant Manager
Coal Policy Section
Resources Division
Department of Industry, Tourism and Resources (DITR)
Australia

Coal Supply Outlook in Australia

Ms Louise Tamaschke
Assistant Manager
Mining Industries Branch
Resources Division

Outline of the presentation

1. Coal supply and demand outlook
2. Infrastructure to support growth in demand
3. Clean coal technology developments inAustralia
4. Australian energy policy settings

Australian Coal Industry Locations

AUSTRALIAN COAL INDUSTRY - OVERVIEW•

Export oriented industry – meeting world needs as a secure,reliable and competitive supplier of high quality coalsWorld's largest exporter – 30% of world coal market
Production 330.3 Mt; exports 244 Mt (74% of production)
Export value was near A$22 billion in 2006-07
Australia's biggest single export commodity (16% of commodity
exports).

Australia's Contribution to World Coal Exports
World Coking Coal Exports
200
160
120
80
40
0
Australia

United States
2005

Canada2008

Rest of W orld

2012

World Thermal Coal Exports
250
200
150
100
50
0
Aus tralia

Indones ia

South Africa
2005

Source: ABARE

2008

2012

China

Res t of World

China’s thermal coal trade100

Imports

Exports

75

50

25
Mt

0
2001

2002

2003

2004

2005

2006

2007

2008

World metallurgical coal imports
75

2006

2007

2008

60

45

30

15

EU 27

Japan

China

Korea, Rep.
of

ChineseTaipei

India

BrazilCoal projects committed, April 2007
Commodity

Project

LocationStart date

Capacity
increase

Metallurgicaland thermal

DawsonProject

QLD

Late 2007

5.7Mt

Metallurgical

Lake Lindsay

QLD

2008

4Mt

ThermalClermont

QLD

2009

12Mt
(replacement
for Blair Athol)

ThermalBulga UG

NSW

2009

6-8Mt
(replacement
for Beltana)

ThermalWambo UGNSW

Mid 2007

3Mt

Thermal andmetallurgical

Glendell

NSW

Mid 2008

2Mt

Australia's planned port infrastructure projects
Port

Capacity as at 31 Dec
2007(Mtpa)

PlannedCapacity by 2012
(Mtpa)New South WalesPort Waratah Coal Services
Newcastle Coal Infrastructure GroupPort Kembla

102
16

120
30
16

Queensland
Abbot Point
Brisbane
Dalrymple Bay
Hay Point
Gladstone

21
5
68
44
68

50
5
85
44
>69

Total

324

419

Clean coal technology and access to sustainable energy•

Future access to sustainable energy requires the development of low emission
coal technologies involving carbon capture and storage.
In Australia, these technologies are needed because coal accounts for 80% ofAustralia's electricity and energy demand is growing strongly
The bulk of world energy demand will continue to be met from fossil fuels and thesetechnologies are needed to reduce emission in a carbon constrained world
Australian coal exports may contribute up to 1.3% of global greenhouse gas
emissions.

•This is why Australia places a high priority on the development and demonstrationof carbon capture and storage technologies.

•

We are doing this through collaboration between government, industry andresearchers in Australia and through practical international collaboration.

Collaboration within Australia - COAL21 Action Plan•

National strategy to advance the development anddeployment of technologies to reduce future
greenhouse emissions from coal power.

•

The first phase to 2015 supports the development
and demonstration of key technologies, including
Carbon Capture and Storage•

The commercial deployment phase is expected tocommence from around 2015.

•

This timetable is supported by the AustralianGovernment through– Energy White Paper (2004)– $500 million to support the demonstration of
low emission technologies (LETDF)– Proposed Clean Energy Target– Proposed Emissions Trading Regime•

Australian coal producers supporting research anddemonstration through the $1 billion COAL21 Fund

Progress in demonstrating low emission
technologies in Australia•

CO2 storage – GeoDisC, Otway pilot project, Gorgon LNG project,
ZeroGen Dennison Trough•Oxyfuel combustion – Callide A retrofit•

Post combustion capture – CSIRO pilot retrofits, Fairview enhanced
coal bed methane, Hazelwood brown coal retrofit•

Coal Gasification – HRL IDGCC, Monash project (brown coal to liquids)•

Coal Gasification with CO2 Capture and Storage – ZeroGen project,
BP/Rio Tinto DF3 project•

Advanced coal preparation – possible Ultra Clean Coal power stationin China•

Lignite dewatering - HRL IDGCC, Hazelwood retrofit

Overview
Since 1996, the Australia Government has committed over $3.5 billion to domestic andinternational climate change response measures
Key Milestones:
1992

Australia signatory to United Nations Framework on Climate Change (UNFCCC)

1997

Created worlds first dedicated climate change agency – AGO
Mandatory Renewable Energy Target (MRET) introducedCommitment to meet Kyoto target of 108%

2003

Founding member of the Carbon Sequestration Leadership Forum2004

Energy White Paper (EWP) - set a comprehensive strategic direction for energy policy and energy
security in a carbon constrained future

EWP measures to support low emission technologies Solar Cities, LEDTF, REDI, CCS development, energy
market restructure, biofuels.

2006

Founding member of the Asia Pacific Partnership on Clean Development

2006

Nuclear Energy Review – identified a need for a carbon price2007

Established the Australia-China Joint Coordination Group on Clean Coal Technology
Emissions trading decision by no later than 2012 – recognises trade exposed industry
APEC – Sydney declaration – aspirational global emission reduction goal
Clean Energy Target to expand mandatory targets to include energy sources with less than 200 kg of CO2 /MWhAustralia Emissions Trading Design(AETS)•

Based on a 'cap and trade' system.

•

Periodically recalibrated by government in response to changing internationaland domestic circumstances through regular transparent reviews.

•

Maximum practicable coverage of all sources and sinks, and of all
greenhouse gases (around 70% of total emissions).

•

Transitional arrangements for trade exposed/emission intensive
industries.
A system of permit allocation that provides an up-front, once-and-for-all,free allocation of permits as compensation to existing businesses
identified as likely to suffer a disproportionate loss of value due to theintroduction of a carbon price.

•

Recognition of a wide range of credible domestic and international carbon
offset regimes.

•

Capacity, over time to link to other national and regional schemes.

•

Complementary measures in a number of areas may be required.

Clean Energy Target
•

•

•
•
•
•

The Clean Energy Target (CET) is a mandatory requirement that
30,000GWh of clean energy (lower than 200kgCO2/MWh) be generated
by 2020.
It will build on the world's first Mandatory Renewable Energy Target(MRET) which has stimulated $3.5 billion of investment in renewableenergy technologies since 2001.
The CET will be expanded to include a broad range of low-emission
technologies such as carbon capture and storage.
The national CET will replace the patchwork of existing and proposed
state and territory schemes.
It will be in operation no later than 1 January 2010.
It will complement the recently announced Australian Emissions Trading
Scheme (AETS) by providing a further incentive for deployment of
renewable and low-emission technologies while waiting for the AETS tomature.

APEC 2007 – strategic movement in the right direction
Sydney declaration:•

APEC countries agree to work a common understanding on acommon long term aspirational goal to pave the way for an effective
2012 international arrangement through the UNFCCC•

Why aspirational? – because climate science is evolving – would be
imprudent to commit to a target, the effectiveness of which is not
fully understood•Significance - first time that major players in the UNFCCC haveindicated the need to establish global emissions target as it breaks
the UN negotiating deadlock

Key messages• Australia has a strong and strategically focused coalindustry well placed to meet growing demand in the
Asia Pacific region.
• Australia is expanding production and infrastructure
capacity to address current bottlenecks and meet thisgrowing demand for coal in the medium and longer
terms.
• Australia is making a leading contribution to thedevelopment, demonstration and deployment of low
emission technologies.
• Australia is working through APEC and otherinternational fora to support the international
development and transfer of low emission technologies.

Department of Industry,
Tourism and Resources
Industry House
10 Binara Street
Canberra City, ACT 2607, Australia
Telephone +61 2 6213 7279

Day 2 Tuesday 16 October 2007
Session 6: Coal Supply Outlook

Speech 3 Indonesia
Coal Supply Outlook in Indonesia

Dr. Ir. Sukma Saleh Hasibuan
Director
Directorate of Mineral, Coal & Geothermal Program Supervision
Ministry of Energy and Mineral Resources (MEMR)
Indonesia

DR. Ir. SUKMA SALEH
HASIBUAN, ME
Place of Birth: Tanjung Balai, North Sumatera, Indonesia
Date of Birth: April, 7th, 1951
Nationality: Indonesia
Institution: Directorate of Mineral, Coal and Geothermal Program Supervision,
Directorate General of Mineral,Coal and Geothermal
The ministry of Energy and Mineral Resources,Indonesia
Position: Director
Office Address:Jl. Prof. Dr. Soepomo SH No. 10, Jakarta Selatan, Indonesia
e-mail : sukma@esdm.go.id
PROFESSIONAL EXPERIENCES:
2007 – now :Director of Mineral, Coal and Geothermal Program Supervision, Ministry of Energy and Mineral
Resources
2004 – 2007:Head of Center for Energy and Information Energy on Mineral Resources Center, Ministry of Energy
and Mineral Resources

DR. Ir. SUKMA SALEH
HASIBUAN, ME
2001 – 2004:Secretary of Educational and Training Agency for Energy and Mineral Resources, Ministry of Energy
and Mineral Resources
1995 – 2001:Head of Division for Compilation and Reporting Program, Directorate General of Mines, Ministry ofMine and Energy
1993 – 1995:Head of Section for Counseling, Directorate Technique of Mines
1983 – 1993:Head of Section for Mining Effort, Directorate Technique of MinesEDUCATION :1 Bandung Institute of Technology, Bachelor on Mining Engineering (Graduated 1978)
2 Sendai, Japan of Tohoku University, Master Degree on Engineering (Graduated 1987)
3 Sendai, Japan of Tohoku University, PhD on Engineering (Graduated 1990)

OUTLOOK COAL SUPPLY AND DEMAND IN INDONESIA
2007 Clean Fossil Energy Seminar
Xi’an, China, 15 – 17th October 2007

By
Dr. Sukma Saleh Hasibuan

Directorate General of Mineral Coal and Geothermal
Ministry of Energy and Mineral Resources The Republic of Indonesia

………Introduction

COAL RESOURCES AND RESERVES
1,58%

28,37%

7,58%

4,07%

40,13%NO

ISLAND

17,7%

QUALITY (Calory(Calory))

CRITERION(gr/cal)gr/cal)RESOURCES(Mill. Ton)

RESERVES(Mill. Ton)

1

JAWA

LowLow-Medium
HighHigh-Very High< 5100 – 6100
6100 - 7100

19,24
2,97

0,00
0,00

2

SUMATERA

LowLow-Medium
HighHigh-Very High< 5100 – 6100
6100 – 7100

26.872,5
1.780,66

2.636,62
134,11

3

KALIMANTAN

LowLow-Medium
HighHigh-Very High< 5100 – 6100
6100 – 7100

25.375,69
6.844,44

2.769,01
1.219,1

4

SULAWESI

LowLow-Medium
HighHigh-Very High< 5100 – 6100
6100 – 7100

218,42
14,68

0,06
0,00

5

MALUKULow< 5100

2,13

0,00

6

PAPUA

LowLow-Medium
HighHigh-Very High< 5100 – 6100
6100 – 7100

120,35
30,91

0,00
0,00

61.273,99

6.758,90

Total Resources in 2006

………Introduction• Situation of Coal in Indonesia :Coal resources 61. 27 BT, Mine able Reserve 6.7 BT, mostly
Low-Rank Coal•

Lignite 58.6 %•Sub Bituminous 26.6 %•Bituminous 24%•

Anthracite 0.4.

34.7 BT (+ 60 %) Indonesian’s coal potential having Calorific valueless than 5,100 Kcal/kg

INTRODUCTION• Indonesia is the world’s largest exporter of thermal coal.
• It is one of the leading exporters of sub-bituminous coalthat represents the bulk of Indonesian coal production

Continued

………Introduction

•

•

•

•
•
•

Oil is still the most important commodity to support thenational economic development to meet the energy
consumption demand.
The level of oil utilization to oil reserve is estimated about
10 years, and Indonesia may become a net-oil importer
before 2015.
Coal will play very important role for Government ofIndonesia to shift the grand strategy of energy utilizationand consumption, and the security of energy supply.
For the times being, coal sector in Indonesia is still continue
to grow.
A few years ahead Indonesia coal production will steadily toincrease.
The coal sector contribution into Indonesian economic
recovery will be more significant.

CURRENT COAL DEVELOPMENTz

The grand policy and strategy may include Optimizing asfollows:- The National Energy Mix;
- Energy resources development;- Energy allocation among the various activities;- Energy allocation in order to generate state revenue

…….Current Coal Development• Indonesian Government has introduced a National Coal Policy (NCP)
in the framework of national energy development .
• NCP is a guidance for promoting coordination and harmonization in
management, exploitation, utilization and development of coalresources within period 2005 -2020.
• The NCP Program divided into three period of time :- Short Term Program until the year 2005;- Medium Term program until the year 2010;- Long Term Program until the year 2025.

continued

…….Current Coal Development• Coal is developed as part of diversification energy policy.
• Coal development policy may include how to increase coal production :- to meet ever increasing domestic coal demand on sustainable basis;- to enhance coal competitiveness in the international market;- to develop all coal qualities and add value through both energy andnon energy applications;- to ensure the growth of the coal industry consistently with the conceptof sustainable development and environmental protection• Export are expected more increase in realization 2007
• About 60% of coal export went to East Asia such as Japan, South Korrea, Taiwan,
Hong Kong, less than 10% to ASEAN Countries, and about 15% to Europe, andmost of which will continue to go to the Asia-Pasific market.
• Indonesia will continue to export of coal in order to increase our country income
and also to increase the domestic utilization of coal

…….Current Coal Development

Indonesian Coal Mining Industry Projection
370

400
320

(Millions Tonnes

280

300

225
193

200
100

148

220

198

183
134

240

145

45

49

53

2006 ®

2007

2008

150

150

75

90

2009

2010

150
130

170

150

150

0

Domestic

Export

2015

2020

2025

Production

NOTE;-. Realization production 2006 (32 PKP2B = 162 M ton, KP- PTBA = 9.2 M ton, 130 Regional KP = 22 M ton);-. Production increase in 2006 due to increase of PKP2B production 10 M ton ( PT Adaro Indonesia, PT
KPC and PT Indominco Mandiri) and increase of Regional KP production 12 M ton;-. Projection of 2006 based on production of 32 PKP2B+ KP-PTBA = 158 M ton and 34 regional KP = 10 M
toncontinued

…….Current Coal Development

COAL DOMESTIC CONSUMPTION 2005-2025
Consumer

1. Electricity

2004
( R)

2005

2010

2015

2020

2025

Remarks

23.0

26.2

49.2

74.8

119.2

156.5

Electricity growth7%
In average 1 ton coal
= 6.6. ton cement
resulted

2. Cement

5.5

6.5

10.0

11.00

13.0

17.0

3. Metalirgy industry
and Pulp peper

1.3

1.5

7.0

10.0

11.0

12.0

5.0

7.0

9.0

10.0

Direct Use+ briquette

UBC Product forexport

4. Small Industries(textile, briectburning
roof/llimstoneroof/llimstone,, etc)

0.02

1.0

5. UBC

-

-

1.7

8.5

17.0

25.5

6. Liquefaction

-

-

2.0

10.8

27.0

37.8

122.1

196.2

258.8

Total

29,82

35.2

74.9

continued

…….Current Coal Development

INDONESIAN COAL PROGRAM
1. Convert the diesel-fired power plant, which have 7,753 megawatts(MW) capacity, into coal-fired power plants and build 10,000 MWcapacity new coal-fired plants in year 2009/2010.
Total demand of Low Rank Coal for development of power plants in2010 is approximately 72,3 Million ton, using lignite coal for 17.753 MW
electricity. The total demand of coal for electricity in the year 2015 will
be app. 90 million ton and 2025 will reach 200 million ton.
2. To achieve securing coal supply, the Government is providing an
incentives for low grade coal development, underground mining,marginal reserves, and coal mining development in remote areas inorder to encourage investment in such areas.

continued

…….Current Coal Development

Current Situation of Coal Industry :• Mining Authorization Holder (MA) : 442 Compaies- Production Stage : 169 Companies- General Survey and Exploration Stages : 273 companies• Coal Contract of Work (CCoW): 81 Companies- Production Stage : 35 Companies- General survey, exploration, feasibility and construction stages : 46
Companies

continued

…….Current Coal Development

The Government Mechanism for Resources Management inRegional Authonomy era• Since 1 January 2001 the authority to manage natural resources has beentransferred to Autonomous Regions (Base on the location of Mining Area)• Mineral and coal development in term of “licencing authority” shifted to theregional government.
• The central government concentrate on the National Mineral and Coal Policy
and give direction fo the implementation of such policy in term of guidance andstandard.
• The regional government will honour the above policy both for executing the“mining development” as well as for the “local rules” issued.
• Coal Contract of Work (CCoW) still managed by central government(Directorate General of Mineral, Coal and Geothermal).
• The Central Government continous to give counseling to the autonomous
regions concerning various matters regarding the management of mineral
resource.
continued

…….Current Coal Development

The Challenges of the Mining Industry in Indonesia
 Long Term Contracts;
 Taxation System and Royalties;
 Conflict in Regions; Illegal Mining activities;
 Overlapping with forestry areas; Environment issue;
 And other certainties in Laws and Regulation throughout
Indonesia.
continued

Government’s Effort…….Current Coal Development

The Government effort to resolve the challenges are :• Issuing a Ministerial of Energy and Mineral Resources Decree No:
1614/2004 regarding Guidelines on Application Process of Contract ofWork (Cow) and Coal Contract of Work (Cow);• Issuing of Law 19/2004 on the amendment of Forestry Law No.41/1991;• Determination of National Coal Policy;• A draft of Amendment of Government Regulation has been also
prepared to settle fiscal problem;• Finalization discussion for the Draft of Mineral and Coal Mining Law asreplacement of the Mining Law No. 11/1967.

continued

…….Current Coal Development

THE BASIC PRINCIPLE OF NEW LAW OF MINERAL AND COAL MINING¾

One type license or mining permit, no more contract
applied between mining company and the government;¾

Foreign mining company will be taken contract with theState Owned Mining Company;¾

Simplification of Licensing Permit stages; Exploration and
Exploitation;¾

Determination of mining areas through bidding and self
reservation;¾

Community development is focused for local people
welfare;continued

CONCLUDING REMARKS
1. The present situation is showing tentative signs that with thegovernment right policy framework and a strong commitment
to reform, the coal mining sector will get clarity and certainty torestore investor confidence.
2. The coming Mineral and Coal Mining Law hopely will create abetter mining development in Indonesia in terms of:- good investment climate;- clear of authority among Central Government, Provisional
Government and District Government;- adopted the “sustainable development” principal- giving the maximum for the people walfare.

Day 2 Tuesday 16 October 2007
Session 6: Coal Supply Outlook

Speech 4 Russia
Coal Supply Outlook in Russia

Mr. Dmitry Sokolov
International Researcher
Center for Energy Research, Northeast Asia (CERNA)
Korea Energy Economics Institute (KEEI)
Korea
Secondered from Energy Systems Institute (ESI)
Siberian Branch of the Russian Academy of Science (SBRAC)
RussiaCo-author
Prof. Boris Saneev
Deputy Director
Dr. Alexander Sokolov
Head of Laboratory
Energy Systems Institute (ESI)
Siberian Branch of the Russian Academy of Science
Russia“Harmonious and Sustainable Coal Power Generation”
APEC Clean Fossil Energy Seminar

Coal Supply Outlook in Russia
Dmitry Sokolov, CERNA, KEEI
Prof. Boris Saneev, ESI SB RAS
Dr. Alexander Sokolov, ESI SB RAS
Zhangdagou Guesthouse, Xian, China
October 15, 2007

1. The Role of Coal Industry
in Fuel-Energy Complex of Russia

21.1. Dynamics of main indices of FEC
operation in Russia in 1990-2006
1990

2000

2003

2004

2005

2006

Electricity generation, bln kWh

1082

878

916

932

953

991

Oil and gas condensate
production,
mln t

516

323

421

459

470

480

Gas production, bln m3

641

584

620

633

636

656

Coal production, mln t

395

258

277

284

300

309

Oil refining volume, mln t

254

173

190

195

207

218

Oil refining depth, %

67.0

70.6

69.9

71.4

71.5

76.2

Motor gasoline production, mln
t

40.9

27.2

29.3

30.5

32

34.5

Diesel fuel production, mln t

74.7

49.0

53.7

55.4

60

64

Fuel oil production, mln t

92.0

48.3

54.4

53.4

56.5

59.1
3

1.2.Primary Energy Resources Production
Oil

Natural Gas

600

600
458.8

470

480.5

488.2

499.9

520.8

531.9

538.2

550.9

2003

2004

2005

2006

421.4
379.6

400

348.1

mln toemln toe

400

200

200

0

0
2001

2002

2003

2004

2005

2006

2001

Coal

2002

Hydro & Nuclear

400

400
mln toe600

mln toe

600

200
128.2

121.9

131.7

135.4

142.8

144.5

200
70.8

69.3

69.2

73.5

73.5

75

2001

2002

2003

2004

2005

2006

0

0
2001

2002

2003

2004

2005

2006

1.3.Structure of primary energy production
100%

3.0
3.8

3.0
3.5

3.0
3.1

2.7
3.4

2.8
3.2

12.4

10.8

11.0

10.8

11.7

47.2

47.0

45.8

44.6

44.0

90%

80%

70%

60%

Nuclear
Hydro

50%

Coal
Natural Gas

40%

Oil
30%

20%

33.6

35.7

37.1

38.5

38.4

2001

2002

2003

2004

2005

10%

0%

5

1.4. Commodity Structure of Russian Export
Export of energy resources (rounded-off)

Production ofChemical Industry
6.0%

Timber, pulp and
paper
3.5%
Other
6.7%

Machines andEquipment
5.4%

2001

2002

2003

2004

2005

2006

Coal, mln t

42

50

60

78

80

87.4

Oil, mln t

165

190

228

256

265

261

47

54

63

65

72

76

Gas, bln m3

180

180

185

193

200

207

Electricity,
bln kWh

16

11

13

7

20.5

20.5

Oil products,
mln t
Fue l and Ene rgy

Production ofMetallurgy
14.6%

63.8%

2005

6

Coal Supply Outlook in Russia

2. Characteristics of Russian Coal
Industry7

2.1. Reserves
As of 01.01.2006 the coal industry of Russia numbered :Forecasted Resources - 4498 bln t
Balance Reserves- 279.6 bil t
Reserves and potential resources

Coal

Reserves registered by Statebalance of RF
Total
Total

Total

including
A+B+C1

C2

Potential
resources4769.8

271.8

193.8

78

4498

- Brown

1474.1

147.1

101.8

45.3

1327

- Hard3261.6

115.6

85.3

30.3

3146

Incl.: - Coking

444.2

48.2

39.5

8.7

396

34.1

9.1

6.7

2.4

25

- Anthracites

Suitable for surface mining
Total

431.4

172.4

118.2

54.2

259

- Brown

311.9

134.9

93.8

41.1

177

- Hard

118.7

36.7

23.9

12.8

82
8

2.2. Production Capacities

10% 80% 10%

Coal Basins- 22
Deposits - more then 1700
Operating coal producing
enterprises: 240 (97 minesand 143 open-pit mines)
Total annual production
capacity - 324.6 Mt.
Washing mills - 41

1. Central 2. Central-Chernozemic 3. East Siberian 4. Far Eastern
5. Northen 6. North Caucasus 7. Northwestern 8. Povolzhye
9. Urals 10. Vogo-Vyatka 11. West Siberian 12. Kaliningrad

92.3. Production
1990 2000 2001 2002 2003 2004 2005 2006
395

258

269

256

284

300 309.2

Underground mining

176

90

95

87.7 93.5 102

105 108.7

Surface mining

219

168

174

168

195 200.5

Production, total, mln t

277

Including:

Level of surface mining , %

183

183

55.5 65.1 64.7 65.8 66.2 64.2 65.1 64.7

Including :Hard coal production, Total

260

172

187

182

197

212

225 234.0

Including: Coking coal93.1 62.3

66

63.6 69.7 75.1 69.9 70.3

Brown coal production

136 86.2 82.1 74.2 79.4 72.3 74.7 74.8

10

2.4. Coal Supply
Domestic and Export Coal Supply 2000-2006

Domestic Coal Supply Structure, 2006

Russian Coal Export by Destinations,2005

11

2.5. Coal Prices
100

Price on gas

90

94

Price on coal
86

80

80
74

70

68
62.3

$/tce

60

58
54

50

50
46.5

47

44.5

46

43

44

45.5

42.5

43.5

45

42
42

2005

2006

2007

2008

2009

2010

2011

2012

2013

2014

2015

46
41.5

40
35.6

30
26.5

20

20

10

10

37.8

29.7

22.3

0
2001

2002

2003

2004

12

2.7. Key Problems of Russian Coal Industry
Development and Strategic Goals and Tasks-

Key Problems- Low share of coal in energy balance of Russia- High share of brown coals in domestic consumption- The quality of coals mined tends to deterioration- Environmental damage caused by coal production- Delay with introduction of new technologies
High railway tariffs and insufficient seaport infrastructure development- Low level of coal processing- Delay with introduction of new technologies

Strategic Goals and Tasks- Reliable provision of the economy and population of the country with high-grade solid fueland products of its processing- Assurance of competitiveness in the context of market saturation with alternative energy
resources- Stable and safe development of the coal industry on the base of up-to-date scientificand technological potential and technologies adequate to environmental standards
133. Coal Supply Outlook in Russia

143.1. Forecast of Coal Production in Russia for the
Period up to 2030
Forecast of coal production in Russia by economic regions, Mt
Economic region

2005

2010

2015

2020

2025

2030

13.2

15.0

19.0

23.0

26.0

29.0

13.0

14.3

18.7

23.8

25.8

28.8

Central

0.6

0.6

1.0

1.0

1.0

1.0

Southern (North-Caucasus)

7.7

9.0

11.0

11.0

12.0

13.0

7.7

9.0

11.0

11.0

12.0

13.0

Ural

4.7

5.0

5.0

5.0

5.0

5.0

West-Siberian

167.6

189.8

197.0

202.0

214.0

236.0

166.5

187.6

194.8

199.5

211.0

233.0

73.6

83.0

101.0

115.0

139.0

158.0

36.7

40.0

50.0

63.0

74.0

80.0

Far Eastern

32.5

37.6

46.0

63.0

73.0

78.0

TOTAL

299.9

340.0

380.0

420.0

470.0

520.0

Northern
Incl. Pechora

Incl. Donetsk

Incl. Kuznetsky
East-Siberian
Incl.. Kansk-Achinsky

1. Central 2. Central-Chernozemic 3. East Siberian 4. Far Eastern
5. Northen 6. North Caucasus 7. Northwestern 8. Povolzhye
9. Urals 10. Vogo-Vyatka 11. West Siberian 12. Kaliningrad

Sources: Authors’ estimates15

3.2. Forecast of Domestic Coal Demand andExport in Russia
Mtce/Year
2005

2010

2020

2030

Coal for coking

40.5

42.3

46.8

54

Power plants

69.4

91.6

127.4

164.3

Boiler plants

19.6

18

17

15

Other consumers

13.1

13.8

18.9

24.8

Export

72.1

76.5

85.5

103.5

16

3.3. Forecast of Coal Balance in Russia
Mtce/Year
Calendar Year

2005

2010

2015

2020

2025

2030

(A)

204.0

231.2

258.4

285.6

319.6

353.6

To Asian region

10.6

11.0

10.0

10.0

9.0

8.0

To other regions

0.0

0.0

0.0

0.0

0.0

0.0

total

(B)

10.6

11.0

10.0

10.0

9.0

8.0

To Asian region

15.0

16.2

18.0

25.2

28.8

31.5

To other regions

57.1

60.3

63.0

60.3

63.0

72.0

total

72.1

76.5

81.0

85.5

91.8

103.5

142.4

165.7

187.4

210.1

236.8

258.1

Production
Import(B)

Export(C)

Total Supply(D) =A＋B-C

Domestic
Supply to:

Power

a

69.4

91.6

107.3

127.4

150.0

164.3

Iron & Steel

b

40.5

42.3

45.0

46.8

49.5

54.0

Cement

c

0.3

0.4

0.4

0.4

0.5

0.5

Others

d

32.2

31.4

34.7

35.5

36.8

39.3

Total Demand (E) =a+b+c+d

142.5

165.7

187.4

210.1

236.8

258.1

Balance (F) = (D) - (E)

0.0

0.0

0.0

0.0

0.0

0.0

17

Thank you very muchfor your kind attention!

18

Day 2 Tuesday 16 October 2007
Session 6: Coal Supply Outlook

Speech 5 Vietnam
Coal Supply Outlook in Vietnam

Dr. Kieu Kim TrucManagerInternational Relation Business Department
Institute for Mining Science and Technology (IMSAT)VINACOMIN Group
VietnamKIEU KIM TRUC
国籍:越南
出生日期:1958.9.7
出生地:越南河内
工作经历:
1982-1996

矿业科学技术研究院(IMSAT)研究员

1996

矿业科学技术研究院(IMSAT),地质力学部经理

1997-1999

越南国家媒炭公司,信息、技术和环境发展公司副主任

1999.6-2002.12 矿业科学技术研究院(IMSAT),主任助理,负责应用信息、地质力
学、环境和露天采矿的促进与发展
2003.1-至今矿业科学技术研究院(IMSAT)/越南国家煤矿和工业集团
(VINACOMIN),国际商务与关系部部长

发表文章:
在越南煤炭矿业领域地理信息系统、采矿地质模型、储量估算、地质资料库
和斜井稳定性与地面沉降专业发表大量文章,其中:30余本研究著作、科学著作20篇
和15篇研讨会文章.

KIEU KIM TRUC
- Nationality: Vietnamese.
-

Birth: 7 September, 1958; in Hanoi, Vietnam.

Residence add.: 309 K8 Bach Khoa, Hanoi, Vietnam.
Job History:
Institute of Mining Science and Technology (IMSAT)/Vietnam National Coal and MineralIndustries Group (VINACOMIN); Manager of Department of International Business and Relation;
Since 1/2003IMSAT, Director Assistant, 6/1999 – 12/2002, in charge of issues on promotion
and development of Applied Informatics, Geomechanics, Environment and Open pit Mining.
Company for Development of Informatics, Technology and Environment (ITE) / Vietnam
National Coal Corporation, Deputy Director, 1997-1999.
-

IMSAT, Manager of Department of Geomechanics, 1996.

-

IMSAT, Researcher, 1982-1996.

Publications:
Several output reports (about 30 study-result books), scientific papers (20), seminarpresentations (15) on issues of coal and minerals in Vietnam specified in fields of Geographical
Information System, Geological and Mine Modeling, Reserve Estimation, Geological Database,Slope Stability and Land Subsidence.

Vietnam country report
越南国家报告Coal Demand and Supply
Outlook for Vietnam
越南煤碳供求的总体概况
K. K. TrucVietnam National Coal &Mineral Industries Group

越南国家煤炭矿石工业集团Vietnam economic growth
2. Coal reserve
3. Coal production
4. Coal demand and supply
5. Promotion to ensure
development of coal sector
1.

1.
2.
3.
4.
5.

越南经济增长
煤炭储存量
煤炭产量
煤炭供求
促进煤炭行业的发展

1. National profile 越南轮廓
♣ Land area: 328943 km2.
♣ Population (2007 e): 85 millions♣ GDP (2006): 48.4 bl US$ (ppp 263$)♣ GDP Growth rate陆地面积: 328943 km2.
♣ 人口 (2007 e): 85 百万♣ GDP (2006): 48.4 bl US$ (ppp 263$)♣ GDP 增长率♣ 2000-2005: 7.5 %
♣ 2006: 8.2 %
♣ 2007 e.
: 8.5 %
♣ 2008 e.
: 9.2 %
♣


♣
♣

♣
♣

Swift from centrally-planning management to market mechanism
economy.
Fast economic growth over past 5 years and next 10 years
Fast Coal demand growth of 11% yearly to 2025.
中央计划管理经济体制迅速地向市场经济体制转变.
在过去5年及未来10年经济快速增长。
直到2025，全国煤炭每年以11％速度快速增长

2. Coal reserve
煤炭储存量









Coal
abundant,
3
places:anthracite, brown, peat.
Anthracite reserve to -300 m - 4
bln.t, to –100m- 1.2 bln.t. Quality
high: calorific value 7000
kcal/kg; ash:10-27%; sulfur< 1%.
Big resource of sub bituminous in
Red River Delta, 250 bln.t.,
proven and probable 1.5 bln.t.
Peat coal in Mekong delta,
reserve: 10 bln.t.
Some fat coal in the North
Big resource of thousands billions
tones forecasted under sea waterof Vietnam continent shelf











煤炭充裕, 分别在3个地区，煤种分别为：无烟煤、褐煤
和泥煤无烟煤储存量从-300 m - 4
bln.t, 到 –100m- 1.2
bln.t. 质量高: 热值：7000
kcal/kg; 灰分:10-27%;含硫量< 1%.
在红河三角洲蕴含着巨大的低 能 位 烟 煤 资 源 大概 有250
bln.t., 已经证明可以能有
1.5 bln.t.
在湄公河三角洲泥煤蕴藏:
10 bln.t.
在北方蕴含着一些肥煤
上千万吨可预见到的巨大资
源蕴藏在越南半岛大陆架上distribution of coal deposits in Vietnam(Exclusive of off-shore deposits)
越南煤矿的分布(不包括近海处的煤矿)

Red Riverconcave area
红河凹面区域§a River Coalfield
河流煤田

Na Duong褐煤Thai Nguyen
Fat Coal肥煤

Quang Ninh
Anthracite无烟煤

Red River Delta Sub
Bituminous烟煤Nghe Tinh
Coalfield 煤田Nong Son Coal
Deposit煤矿
Ba River Coal
Deposit煤矿

Peat Deposits in the
Mekong River Delta
在Mekong River Delta
的泥煤矿

Di Linh Coal
Deposit煤矿Coal Resource Potential, ml.t.潜在煤资源总量

Category A+B
种类 A+B

Category C1
种类 C1

Category C2
种类 C2

Category P
种类 P

6,068.5370.6

2,157.2

2,464.4

1,076.3

4,049.6315.2

1,401.4

1,768.2

564.8- C.Pha

1,962.9

260.3

727.6

530.4

444.5

- H.Gai

740.4

37.5

229.7

446.6

26.6

- U.Bi

1,346.3

17.3

444.1

791.2

93.7

II. Inland- K.Chau,
subbitum

2,018.9

55.5

755.8

696.2

511.4

1,581.0

0

524.9

563.6

492.5

437.9

55.5

230.9

132.6

18.9

Coalfield煤田

Total

Total总量
I.Q.Ninh
anthracite无烟煤-Others其它A and B categories – equal to Proven reserve;
C1 category– Probable and Proven reserve and C2 – Estimated resource.
P category – poorly estimated resource.
So columns of (A+B) and part of C1 can be classified as Proven reserve. Columns of C2 and P can beclassified as forecasted resource.
A和B种类 —— 已经证实的储备;
C1 类—— 可能和已经证实的储备以及
C2 – 估计资源.
P 种类—— 不确定的资源.
因此，A列和B列，在加上部分的C1可以归类为已证实储备. C2列和P列可归类为预计资源.

Comment 说明Exploited over 160 years (since 1840), mostanthracite in Quang Ninh coastal area.
 Majority of proven reserve is anthracite - 4 bl.t.
(68%), lying in QN coalfield (67 %).
 Low rate (42 %) of the proven reserves.
 Red River Delta sub bituminous is abundant, butdifficult geological condition – rich of water,
weak rock, busy surface.
 Continental shelf coal deposits has been
expected rich,but not studied yet.
 Insignificant reserve of Fat Coal – importneeded.

经过160年的开采 (从1840年开始), 大部分
的无烟煤分布在Quang Ninh沿海区.
 已证实的储备主要是无烟煤 - 4 bl.t.
(68%), 位于 QN 煤田 (67 %).
 已证实储备比率很低 (42 %) 红河三角洲亚烟煤是很丰富的, 但是地质条
件很复杂：充足的河水、不牢固的岩石、繁忙的表面.
 大陆架煤矿被认为是丰富的,但是尚未研究.
 肥煤的储备很小——需要进口.
3.Coal production and Vinacomin activity
越南的煤炭生产以及越南国家煤矿采掘工业集团行动
The Vietnam National Coal and Mineral Industries
Group -VINACOMIN) - State owned enterprise.
 VINACOMIN growing up from coal mining tomultibusiness corporation:
 Coal & Mineral exploration, exploitation, Thermal power energy development (6 thermal
power plants are being designed and built),
 explosive production, mine machine manufacturing,ship building and port business, cement production
and construction, services for commerce, tourism...
 Going to mine bauxite ore of huge reserve in Lam
Dong, south of Vietnam.
越南国家煤矿采掘工业组-VINACOMIN)是国有企业.
 VINACOMIN是从煤矿采掘发展而成的多种经营公司
 从事煤和矿物的勘测与开采 从事热力发电能源的开发 (正在设计和建设6个热力发电厂), 从事炸药的生产、采煤机器的制造、 船的制造和港
口经营、水泥生产和建设、商业观光的服务...
 正在越南南部的Lam Dong开发铝矿，那里存有大量的铝矿Rapid development of Vietnam coal industry
越南煤炭工业的快速发展Over 10 y. great changes in production and business activities.
2006, 38 mln.t. growth 19% from 1999 - 2025.
demand increase, 2015 push output to 57 mln.t.
Ratio Undr/Opp increases, 50% in 2015 and more later经过10年的发展,煤炭生产和经营有了很大的变化.
2006为38 mln.t. 从 1999至2025增长率为19%.
需求增加, 2015 输出到 57 mln.t.
地下和露天比例在增加, 在2015为50%，2015后更高





80
70
60
50

Total raw coal output
from O/P minesfrom U/G mines

40
30
20
10
0
1999 2000 2001 2002 2003 2004 2005 2006 2007 2010 2015 2020 2025

4. Coal demand and supply
煤炭需求和供应Domestic demand for coal rapidly increases,from 15 m.t in 2005 to 118 m.t in 2025 (10times); power generation - 15 times...
 While coal production growth is still behind; Coal export has been rapidly increased untilnow The country will face coal shortage since 2015.
 Coal export will be reduced and Coal import willtake place – VN is becoming a coal importcountry after 2020 if output can not be raised.
 越南国内对煤的需求快速增加, 从2005年

的 15 m.t 到2025 年的118 m.t (10 倍); 电力生产增加15 倍...
 然而煤炭生产的增长依然滞后 现在,煤炭出口一直在快速增加 到2015年，越南将面临煤资源短缺的问题 那时煤的出口将会减少,同时会出现煤炭进
口——如果煤炭产量没有提高,到2020年后
越南将会成为煤炭进口国家.

Domestic Coal demand forecasts up to 2025, ml.t.
到2025年的国内煤炭需求预测, ml.t.
By Sectors 部门

2010

2015

2020

2025

11.7-12.3

22.6-23.8

40.0-41.6

76.2-78.5

2. Cement prod. 水泥生产

5.3

6.4

7.1-7.3

7.3-7.9

3. Building mater. 建筑材料

4.9-5.1

5.6-5.9

6.4-6.8

7.3-7.9

1. Power generation

发电

4. Chemical

化学制品

1.1

1.8

1.9-2.8

2.3-3.4

5. Paper

造纸

0.3

0.4

0.6

0.7

6. Textile

纺织业

0.3

0.4

0.6

0.8

7. Metallurgy冶金业

1.6-3.3

4.4-6.3

7.1-7.8

8.0-9.1

8. Others其它

3.8-4.3

5.4-6.0

7.3-7.5

9.4-9.7

Total domestic

29-32

47-51

71-75

112118

国内总量

Coal consumption, ml.t
煤炭消费, ml.t
Consumer
消费者
Total

总量

Domestic
国内-Power product
电力产品-Cement
product-水泥产品-Fertilize.
Product-化肥产品- Paper
product 纸制品- Other sector
其它部门
Export
出口

2001

2002

2003

2004

2005

2006

13.7

16.0

20.0

26.6

33.7

37.7

9.4

10.0

12.7

15.0

15.7

16.1

2.29

2.62

3.85

3.95

4.75

5.47

0.97

0.86

1.15

1.40

2.06

2.17

0.24

0.25

0.36

0.37

0.42

0.38

0.13

0.15

0.12

0.16

0.16

0.17

5.80

6.10

7.25

9.10

8.31

7.91

4.29

6.05

7.26

11.64

18.00

21.6

Coal consumption in 2006
2006年的煤消耗- Power product- Cement product

5.47
2.17
0.38
0.17

21.6

- Fertiliz. product- Paper product

7.91- Other sector
ExportExcept export, most coal is used in energy generation (1250 MW ), another big
part in cement industry
除去出口,大部分的煤用于能源生产 (1250 MW ), 另一大部分用在水泥工业.

VINACOMIN Coal-fired Power Projects
越南国家煤矿采掘工业集团燃煤电厂项目
Coal Demand increases
煤需求增加











Running: Na Duong Plant-110MW, Cao Ngan Plant-110MW
Under construction or projected:
Hai Phong Power Project -1200MW
Quang Ninh (Halam) Power Project - 1200MW
Cam Pha (Cuaong-Quangninh) - 340MW
Son Dong (Bacgiang) - 220MW
Nong Son (Quangnam) - 30MW
Mao Khe (Quangninh)- 220MW
Cam Pha II: 340MW, Cam Pha III: 2 x 135MW After 2010:
DakNong project 600MW for aluminum.
Mong Duong BOT project 1200MW












正在运行的: Na Duong 电厂-110MW, Cao Ngan 电厂-110MW
在建设中或计划中的:Hai Phong 发电厂项目 -1200MW
Quang Ninh (Halam)发电厂项目 - 1200MW
Cam Pha (Cuaong-Quangninh) - 340MW
Son Dong (Bacgiang) - 220MW
Nong Son (Quangnam) - 30MW
Mao Khe (Quangninh)- 220MW
Cam Pha II: 340MW, Cam Pha III: 2 x 135MW
After
2010:
DakNong project 600MW for aluminum.
Mong Duong BOT project 1200MW

• Building power plants in Vietnam of typical 100 MW or 300 MW class PC-type
FBC/CFBC, burning low calorie coal to reduce SO2, NO2 increase efficiency of
combustion. 2 coal-fired power plants (Na Duong, Caongan of 100 MW each) areworking well and new plants (Campha-600MW, Maokhe-440,Sondong-220 MW underconstruction.

• 在越南建立典型的100MW或者300MW等级的PC型FBC/CFBC机组，烧低位发热量的煤以减少SO2, NO2排放,这样做是为了提高燃烧效率. 两个燃煤电厂(Na Duong,
Caongan,分别都为 100 MW)目前运行情况良好,而新电厂(Campha-600MW,
Maokhe-440,Sondong-220 MW)在建设当中Domestic coal demand and supply balance
越南煤的供求平衡
140

Clean coal output

Clean coal volume, m.t.

120

Domestic demand
Export100

Import fat coal
80

import energy coal

60
40
20
0
2006

2010

2015
years

2020

2025

Domestic coal demandand supply balance, ml.t.
越南国内煤的供求平衡, ml.t.
Year
Clean coal output
Domestic demand
ExportImport fat coal
Import energy coal

2006
38.0
17.0
21.0
0.2
0.0

2010
44.2
31.8
15.4
3.0
0.0

2015
49.8
50.7
5.5
6.1
0.0

2020
57.3
75.4
4.2
7.6
13.9

2025
60.3
118.1
3.8
9.0
51.0

5. Promotion to ensure developmentof coal sector
促进煤炭行业的发展










To meet the stable growth and sustainable development in coalindustry, ensuring supply for national economy, many steps andmeasures have to be applied, actually for higher efficiency
technology and environment protection as follows:
Approving Master Plan for Coal Development to 2015 and 2025.
More Geological surveying to find new reserve and build newmines, deeper mines below –300 m height level.
Mechanization of underground mining.
Deep pit mining and joining, enlarging existing pits.
Coal preparation and utilization.
Safety management and environment protection
Legal organization and management为了实现煤炭工业的稳定增长和可持续发展,保证国家经济的发展，越南已经在以下诸方面采取了多种
措施与步骤，以提高效率并进行环境保护: 批准从 2015年到2025年的煤炭资源发展总规划.
 进行更多的地质勘测以寻找新储备和建立新煤矿,
更深的煤矿——300 m 深度以下.
 地下采矿的机械化.
 深坑采矿和连接,扩大已有的煤矿.
 煤的制备和利用.
 安全管理和环境保护
 法律机构和管理Master Plan for Coal Development
to 2015 and look-up to 2025
至2015年和至2025年煤资源发展的总规划







The Master Plan for Coal Development is now under approval
by Government.
Overall purpose is Sustainable development of the coal sector
to meet as much as possible the coal demand of the national
economy.
The Master Plan has detail planning for each production unit
and each branch like mines, washing plants, loading ports andrailway stations, energy and water supply, transport andcommunication, ... up to the year 2015 and general planning
up to the year 2025.
Many figures of the Plan have been used in this presentation.

 煤资源总规划正在政府的审批中.
 总体目标是保持煤炭行业的可持续发展，以满足国家经济对煤资源的要求.
 总规划对每个生产单元和每个部门都做了详细计划,比如说洗涤车间,装货港口和火
车站,能源和水供应,运输和通讯, ... 直到2015年,总体规划做到2025年.
 本次介绍中用到了很多该计划的数据

Implementation of the Master Plan总规划的执行










Mobilization of finance: issuing bank notes, swifting fromstate-owned to shared companies, calling national andforeign investment, locate budget for exploration, loan andaid...
Development of man power, budget for training andeducation, cards selection...
Infrastructure development
Organization and management
融资途径: 银行投资, 从国有转化为参股公司, 吸引国内和国外
投资, 为勘测、贷款和资助进行地方预算...
人力资源的发展, 培训和教育的预算, 卡片选择...
基本设施的开发
组织和管理

More geological exploration and mines
更多的地质勘探和矿产









Geological surveying and drilling to find new coal reserve:
Proved: 286 ml.t, well proved: 127 ml, depth – 600 m; area:
25 km2 in Binhminh commune or 1.5 bl. t. of coal in Red
River Delta, until 2020 to clearly define reserve.
Carrying drill for deeper anthracite under –300 m of sea levelin Quangninh coastal area until 2010.
Estimation of coal reserve with focusing on suitable reserve
for mechanization.
Building geological database with focus on resource
management.
Preparing new mine area deeper –300 m height level.
Building new mine in Binhminh commune of Red River
Delta from the year 2015进行地质勘测和钻井以发现新的煤炭储备: 已证实: 286 ml.t, 得到很好的证实: 127 ml,
深度–600 m；面积: 25 km2 in Binhminh
commune 或1.5 bl. t. 在 Red River Delta的煤,到2020年将有明确的储量说明.
 到2010年，在Quangninh沿海区进行深层钻井（–300m水平线以下），以得到深层无烟煤.
 预测可适应机械化开采的煤储备.
 为资源管理建立地质数据库.
 对新的深层（–300 m）矿井进行准备工作 从2015年开始在Binhminh commune of Red
River Delta建立新矿井.
Mechanization of underground mining
地下采矿的机械化









As ratio between Underground and open pit output will excess 50%
after 2015, mechanization of underground mining is most importantfor Innovation of technology and economic management
Number of long walls supported by hydraulic props with sliding
beams increases remarkably, replacing timber used to be(22 stopes).
Full mechanization of mining by self-advanced powered supports
and coal shearer are being applied and widespread widely frombeginning of 2007 up to now - 8 stopes at 6 mines, will double at 11
mines until 2010.
Vinacomin is now manufacturing shield supports (VinaAlta- for 1sttime to apply in Vangdanh mine).
Reserve that can be mined by mechanized method is defined as 165
ml.t. (23.4 % of total geological).
Resin bolts, driving machine are being applied to roadway (model
AM75, AM100). Anchor supports for coal drift are tested andmultiplied









因为2015年后地下和露天矿井的产量比例要超过50%, 所以地下
采矿的机械化对于技术的改革和经济管理是最重要的.
用滑梁通过液压支柱支撑起来的长墙的数量会大量增加,以取代过去使用的木材 (22 个采矿场).
从2007年初到现在，正在采用具有先进的动力支架和刨煤机的完全机械化采矿技术,这一技术将被广泛使用——从目前6个矿
区的8个采矿场到2010年翻倍至11个矿区.
越南国家煤矿采掘工业集团正在制造防护支撑 (VinaAlta- 第一次运用在 Vangdanh 矿区).
以探明的适于机械开采的储备量为 165 ml.t. (总地质的23.4%).
在道路工程中已使用了树脂锚杆和道路挖掘机 (型号 AM75,
AM100). 正在测试和推广用于煤巷的耐张支撑结构.

Deep pit mining






深井采矿

Applying High capacity excavation equipments, Integrated transport, plougphing tractors,mine slope stabilization,
Deepening, joining and enlarging existing pits, which are at boundary limits.

运用高容量挖掘设备、综合运输、先进的拖拉机和斜井的稳定性
加深、连接和扩大现有的、处在边界线的煤井Campha region
with 4 mines
designed to thedepth of -350m
Campha 地区有4个矿区设计的深度为 -350m

Coal preparation and utilization
煤的制备和利用
Perfect the utilization of coal with better effect and cleaner
production and emission (CFB boilers, low calorie coal...).
 Replanning coal preparation plants, build new 3,
centralization and modernization, enlargement of raw coalpreparation, upgrading preparation technologies andequipment for hard washable.
 Building local coal washing cycle to recover coal fromwaste heap and waste of washing plant with technology by
drum separator and barrel separator.
 Development of technology for manufacturing and usingof water coal fuel made from anthracite and coal sludge 合理使用煤炭，使之产生良好的效果、降低排

放量（CFB锅炉，低热值煤种…..）
 重新规划煤的制备设备，建立3座新式的集中式、现代化大型原煤制备工厂，更新煤的制备技术和洗煤设备。
 建立就地煤炭洗煤工厂，采用鼓形分离器和桶行分离器技术从废煤堆以及洗煤设备中的废弃
物中回收煤。
 开发使用水煤浆燃料的设备制造技术，用无烟煤和淤泥煤制作水煤浆。

Legal organization and management
法律机构与管理









Swift from centrally-planning management to market
mechanism, to stop subsidy, to reduce taxis ...
Enhancement of understanding on Clean Coal Technology,
Energy Conservation, Environment, Promoting R&D,
international co..
Issuing regulations, technical norms, laws on and guides torational utilization of natural resources, CCT, EC, andEnvironment...
实现从中央集权管理到依照市场机制的转变，取消补贴，减少税收
加深对清洁能源技术、节能、生态环境的认识，推动研发和国际交流
出台规章制度、技术标准、相关法律和指南，以便合理利用自然资源，洁净煤技术、节能、生态环境Environment protection 环境保护










Coal activities are badly polluting air, water and land, affecting
beautiful Halong Bay recognized by UN as the World Natural
Heritage.
Financing for Environment Fund by 1% of turnover:Rehabilitation and recultivation of dump sites, Cleaning andembankment of streams, Plantation and recovery of forest ...
Monitoring for environment parameters are carried out forsensitive places every year quarter.
Financing for Environment Fund by 1% of turnover or 2 % in2015.
From year 2010, no environment degradation in coal areas;
From 2015, all mining activities must satisfy environment
standards (which used to be not satisfied yet).
After 2025, meeting all environmental requirements in mines
and around mine areas.

煤的使用会严重地污染空气、水和土地, 影响由联
合国认证为世界自然遗产的美丽的哈龙湾。
 对环保基金筹集资金达到1%的周转:恢复和创新开垦垃圾倾倒场, 清理溪流、修复堤坝, 种植树木和恢复森林 ...
 每季度对敏感地点实施环境参数的监测 对环境基金筹集资金达到1%的周转额或者在2015年
达到 2 % .
 从2010年起, 煤矿区环境不再恶化; 2015年起, 所
有尚未遵守环境标准的采矿活动必须遵守环境标准 2025年后, 矿区及周围全部满足所有环保要求。
Halong bay, UN recognized world natural heritage
Halong 湾, 联合国认证的世界自然遗产Conclusion结论

Coal supply is in limit, but demand is soaring
 To meet the requirements of increasing coal output andutilization in a manner of sustainable development,
friendly-impact on environment, Vietnam Authority ingen. and Vinacomin in part. have implemented several
measures and steps.
 But in fact there remain problems, due to backgroundand shortage of modern technology and management, as
well as shortage of finance sources.
 We would like to cooperate with coal agencies all over
the world to develop coal industry in friendly toenvironment manner and safely, making a contribution
to the energy stability in the Region.
煤供应是有限的,但是煤的需求在增长 为了满足煤产量增长以及可持续发展和环境友好的
使用的需要, 越南政府以及越南国家煤矿采掘工业
集团执行了很多措施和步骤 但由于缺乏现代技术和管理、缺乏资金，仍然存在一些问题
 我们愿意和世界上的煤炭资源机构合作,以对环境友
好的方式来发展煤炭工业,从而对地区的能源稳定作出贡献.
Thank you for your attention

Day 2 Tuesday 16 October 2007
Session 6: Coal Supply Outlook

Speech 6 Indonesia
Indonesian Coal Development

Mr. Hadi Nursarya
Head of Affiliation Division
Head
Agency for Research and Development
Ministry of Energy and Mineral Resources (MEMR)
Indonesia

COAL DEVELOPMENTS
IN INDONESIA

Agency of R & D For Energy and Mineral Resources
Ministry of Energy and Mineral Resources

Xi’an, PRC October 15– 17, 2007

1

OUTLINE
1. BACKGROUND- Energy Resources- Targeted Energy Mix by 2025
2. Coal Mining Status (Coal Deposit, Mining
Contractor, Production and Policy)
4. New Coal Power Plant (Fast track 10,000MW)
5. Coal Utilization R&D
6. Concluding remark

TYPE OFFOSSILENERGYRESOURCESRESERVESPRODUCTION

R/P(YEARS)

Oil

86.9 billion bbl

9.1

387 million bbl

23

Gas

384.7 TSCF

185.8

2.95 TSCF

62

CBM (Gas)

400 TSCF---

61.3 billion Ton

19,3

132 Million Ton

146

RESOURCESEQUIVALENTUTILIZATIONINSTALLEDCAPACITY

Hydro

845 Million BOE

75,670 MW

6,851,000 MWh

4,200 MW

Geothermal

219 Million BOE

27,000 MW

2,593,500 MWh

807 MW

458.75 MW

458.75 MW

54 MW

49,810 MW

302.4 MWSolar

4.8 kWh/m2/day

5 MW

Wind

9,287 MW

0.5 MWCoal

NON FOSSIL
ENERGY

Mini/Micro hydroBiomass

Uranium

24.112 Tons**) only in Kalan region, West Kalimantan

3 GW
3

2005

2025

Hydro
Geothermal, 3.11%
1.32%
Gas ,
30%

Gas ,
28.57%
Oil
51.66%

Coal,
15.34%

Others,
17%
Coal,
33%

OthersLEGAL ASPECT
Presidential Decree No. 5/ 2006
Presidential Instruction No. 2/2006

Oil,
20 %

Bio-fuels, 5%Geothermal, 5%
Solar, Wind, etc , 5%
Coal liquid, 2%

Sub Bituminous
26.7%

Anthracite
0.3% Lignite 58.7%

Bituminous
14.3%

1.58%
28.37%7.58%
SU
M

KALIMANTAN
4.07%

AT
ER
A

17.7%

40.13%SULAWESI
PAPUA

JAWA

Resources : 61.3 billion tons
LRC
: 70 %

10.000 MW

STATUS OF COAL CONTRACTOF WORK (CCoW)(December 2006)
Stage
Type of Enterprises

GS

EXPL

FS

CONS

PROD

Sub Total

Termination

GEN. I (1981-1990)

-

-

-

-

10

10

-

GEN. II (1994)

-

-

2

-

10

12

6

GEN. III (1997-2000)

1

10

22

7

16

56

60

Total

1

10

24

7

36

78

66

in million tons

2006

2010

2015

2020

2025

1. Electricity *)

35.5

65.0

93.0

103.0

123.0

2. Cement **)

7.0

10.0

11.0

13.0

17.0

3. Metallurgy Industry andPulp/Paper

3.0

7.0

9.0

11.0

12.0

4. Small Industries

2.5

5.0

7.0

9.0

10.0

5. UBC

-

3.0

7.0

20.0

30.0

6. Liquefaction

-

-

3.0

14.0

28.0

48.0

90.0

130.0

170.0

220.0

Total

*) Growth of 2 % after 2010 (Data compilation of KBN and PLN, 2006)**) Average growth of 12 % after 2010 (Data compilation of KBN and Indonesia Cement Association, 2005) 8

Some Important Issues
In the year 2006/2007, a number of
uncertainties continue to affect the level of
new investment in the mining industry regional autonomy, delay in finalization ofnewmininglaw,
illegalmining,environment, fiscal policy, and over lappingwith forestry law.

BASIC PRINCIPLE OF NEW LAW OF MINERAL AND COALMINING•

Clarification of Central Government, Provincial and District Authority;•

Establishing of Mining Zone; Mining Estate•

Establishing “State Reserve” for the special national interest.

•

Mining license system, no more direct contract applied between mining
company and the government;•

Foreign mining company may have an agreement with the State Owned Mining
Company/Representative Agency to develop “state reserve”;•

Simplification of Licensing Permit; Exploration and Exploitation;•

Determination of mining areas through bidding and self reservation;•

Community development is focused for local people welfare;•

Processing and refinery producing metal must be establish in Indonesia;•

The Existing of License Authority and Agreement will be honored.

FAST TRACK 10,000 MW PROGRAM
Objective:• To replace Oil Based Power Plants with Coal Power
Plan and to deal with electricity crises
Expected Impacts:• Reduce Domestic Oil Consumption• Reduce Fuel Cost for Power Generation• Reduce Electricity Production Cost
• Reduce Subsidy Level• Overcome the Electricity Shortages
11

LOCATIONS OF COAL PP PROJECTS(BASED ON THE ANNEX OF PERPRES NO.71/2006)
PLTU Meulaboh
2x100 MW
B-AcehPLTU Sibolga Baru
2x100 MWPLTU Sulut Baru
2x25 MWPLTU Bengkalis
2x7 MW
PLTU Medan Baru
2x100 MWMedan

PLTU Selat Panjang
2x5 MW

PLTU Pontianak
2x25 MWPLTU Amurang Baru
2x25 MW
Tarakan

PLTU Singkawang
2x50 MWPLTU Tanjung
Balai Karimun
Baru 2x7 MW

Minahasa

GorontaloKotamobagu

Pontianak
PLTU Bangka Baru
2x25 MW

Padang

PLTU Mantung
2x10 MW

Bengkulu

PLTU Belitung Baru
2x15 MWPLTU Tarahan Baru
2x100 MWPLTU Suralaya Baru
PLTU Labuan
2x660 MW1x300 MWPLTU Teluk Naga
2x300 MWPLTU Jabar Selatan
1x300 MWPLTU Tj Jati Baru
1x600 MW12
12Sorong

Palu

Serui

Mahakam

BangkaPLTU Air Anyer
2x10 MWPLTU Ternate Baru
2x7 MW

PLTU Sampit Baru
2x7 MW

PLTU Sumbar Pesisir
Selatan 2x100 MW

PLTU Jayapura Baru
2x10 MW

Ambon

Banjarmasin
PLTU Palangkaraya
2x65 MW

SumselLampung
PLTU Jabar Utara
2x300 MW

Jayapura

PLTU Gorontalo Baru
2x25 MWPLTU Asam-asam
2x65 MWPLTU Kendari
2x10 MWPLTU Ambon Baru
2x7 MW

PLTU Bone
2x50 MW
Kupang
PLTU Rembang
2x300 MWPLTU Jatim Selatan
2x300 MWBima

PLTU Timika
2x7 MW

Sumbawa

PLTU Lombok
Baru 2x25 MW

PLTU Paiton Baru PLTU Bima
2x660 MW2x7 MW

PLTU Ende
2x7 MW

PLTU Kupang Baru
2x15 MWCoal Research and Development

1. Upgraded Brown Coal (UBC)
2. Coal Liquefaction
3. Dual Fuel Power Generator

UPGRADED BROWN COAL
Characteristic of UBC Process
UBC process reduces moisture content of LRC (up to80%) or increases CV of LRC (<5,000 kcal/kg) up to
6,000 kcal/kg (similar to HRC) based on slurry
dewatering process
Feed Stabilizer(Black box)

UBC

Premium Coal
(added value)• Coal Fired Power
Generation• Industry

Export14

STATUS OF 5 ton/day UBC Plant
Goal:
To gather engineering data for constructioncommercial scale UBC plant
Results:
 Various of LRCs have been tested successfully inthe plant Performance of UBC process was successfully
improved
and engineering data was collected to be used forconstruction of semi commercial scale
In Progress:
Construction of 1,000 ton/day coal feed or 600
ton/day product UBC semi commercial plant in South
Kalimantan
15

Goal

Construction of Commercial Plant, 27,000 bbl/day

Resultso Pre-feasibility study (2002) of commercial plant construction in

3 locations (Cost US$ 29/bbl, 1 ton raw coal produces 1,8 bbl oil
o GOI has issued the Presidential Decree No. 5/2006 andPresidential Instruction No. 2/2006 related to the construction ofcoal to liquid

In Progress¾ Engineering Design of 1 ton/day Process Supporting Unite (PSU)¾ Up dating F/S data
¾ Establishing Coal Liquefaction Implementation Body

16

2005

2010
2009

Brown Coal
Liquefaction (BCL)
Process

2015

2020

2025

2013

13,500 bbl/day Semi-Commercial
Plant（Investment: $1.3billion）
2014

27,000 bbl/day 1st Commercial Plant（Total Investment:$2.1billion）
2017

Additional13,500 bbl/day Plant（Investment: $0.8billion） 2018
27,000 bbl/day Commercial Plant X 6
Units （Total Investment: $9.6 billion）

Total Synthetic Oil

Oil Demand

13,500 bbl/day

1.12

1.36

189,000 bbl/day

27,000 bbl/day

1.67

2.04

2.49 million

bbl/day

Total Coal Demand
Share of Synthetic Oil

2.5 million 5 million
0.74%

1.27%

35 million ton/year
7.59%

17

Coal Gasification For Dual Fuel Power Generator

4
3
1 Gasifier
2 Tar Quenching
3 Wet ESP

2

1

4 Diesel Tank
Dual-fuel Power
5
Generator

5• Coal is projected to be the main energy source
in Indonesia by the year 2025
• The Coming Mineral and Coal Mining Law
hopefully will create a better mining
development in Indonesia in terms of goodinvestment climate, clear of authority among
Central Government, adopted the “sustainable
development” principal and giving the
maximum for the people welfare.
• R & D on coal as well as crash programs of coal
fired power plant have been conducted toincrease of coal for domestic use and to
decrease dependency on oil.

19

20

Day 2 Tuesday 16 October 2007

Session 7:
Energy and Water Saving in
Coal-fired Power Plant

Day 2 Tuesday 16 October 2007
Session 7: Energy and Water Saving in Coal-fired Power Plant

Speech 1 PR China
Application of Low Temperature Sea Water Desaltion andCogeneration of Water and PowerMs. Zhang Jiangli
Senior Engineer
Beijing Guohua Corporation
PR China
Co-author
Mr. Chen Yinbiao
Deputy Chief Engineer
Beijing Guohua Corporation
PR China

ChenYinbiao

Chen Yin-biao, who has ever worked in North China Designing
Institute of Electric Utilities for a period after graduating in Thermal
Power Kinetic in a high learning institute in Zhejiang in 1983, iscurrently serving in Beijing Guohua Electric Power Company as a
Senior Engineer and Vice Chief Engineer.

1

ZhangJianli
Zhangjianli, women, graduated form Wuhan Hydraulic and Electric
University ， and works in Beijing Guohua Electric PowerEngineering Technology CO.LTD, Senior Engineer，majors in water
treatment for power plant and sea water desalination.

2

The Research & Application of LT-MED
Technique, and Combined Desalination& Power Plant

Beijing Guohua Electric Power Company

August 2007
3

Main content
1. Background of technical application of thedesalinization
2. Method summary of the desalination
3. the advantages of combined desalination plant withpower plant
4. Desalinization craft characteristic of Huanghua
power plant
5 ． technological research of combined desalination
plant with power plant41. Background of technical application of

the desalinization


Serious shortage of fresh water resourcethe sea water is abundant, with its characteristic not exhausted



Solve the deficient important route of fresh water in the coastal area

Solve the coastal effective scheme of building the thermal power plant ofarea lacking of water5

1. Background of technical application of

the desalinization

The international desalination association in 2007 (IDA) newest statistics
reveals, the whole world has desalinized water daily output and has already beenclose to 50 million cubic meters.

FROM IDA YEARBOOK(2007-08)

6

2. Method summary of the desalinationDesalinization technology mainly includes：
Distillation law, embrane method, electrodialysis law and frozen
law,etc.；
Distillation includes: Multi-stage Flash （MSF）、Multi-effect desalination（MED）&thermodynamics vapour compressor （TVC）；
The embrane method is mainly a sea water reverse osmosis （SWRO）.
low-pressure vapour from steam turbine is adopted as heat source fordesalination method of MSF、MED

7

2. Method summary of the desalination
Main factor influencing the desalination technology tochoose :scale, energy expenses, original sea water quality, climaticconditions, technology and security are required etc..

82. Method summary of the desalination
technological economy of daily desalinization compared
Comparative

SWRO

MSF

MED＋TVC

MVC

Product
quality
Opration
temperature

300∼500ppm< 10 ppm< 10 ppm< 10ppm

Normalatmospherictemperature

∼110℃

< 70℃

< 70℃

preconditioning

Expect much

Expect little

Expect little

Expect little

Electric
energyHeat energy

Heat energy

Electric
energy5.5∼6.5kWh/m3∼8 kWh/m3∼5 kWh/m3∼8.5

relatively big

relatively
small
Expect little
Relatively low

projectof raw materials

ConsumedenergyTotal energy
consumption
Corrode and formmaterials

Expect much

relatively
small
Expect little

Equipment
investment

the highest

highdirt inclination

9

3. the advantages of combined desalination plantwith power plant

combined desalination plant with power plant -----Realize
the sufficient use of low-quality heat energy, reduce theproduction costs of water and electricity effectively.
boilersteam
turbine

Hot recovery
devicegenerator

1 MW installedcapacity can produce
1,000t fresh water
every day

Desalination
deviceFresh water10

3. the advantages of combined desalination plantwith power plantPower plants consume large water, while all generate
electricity water adopt the sea water, 20 billion m3- 30
billion m3 fresh water resource can be saved a year.
The power plant adopts desalinization technology, will
be no longer restricted by fresh water resource by land in
the choice that the power is lighted of coastal area.
With maturity and progress of desalinization technology,
making energy consumption of water can also be further
reduced with the cost, its economic benefits and social
benefit will be further shown especially.

11

4. Desalinization craft characteristic of Huanghua
power plant Country power plant the first stage of the project,
Huanghua of China, install 2×600MW precritical aircrew,
stand and plan capacity of 100,000 ton per days indesalinization, adopt and build the mode by stages.
 Build desalinization scale for 2 daily output ton of MED
TVC devices first stage, mainly consider:z Sea water water quality and environmental conditionz Comparison of various desalinization with economic
technologyz Pump the vapour system to prove with steam turbine
noumenonn structure and steam turbine selected for use
12

4. Desalinization craft characteristic of Huanghua
power plant 2 desalinization apparatus succeed in putting into operation on
March 14 2006. Performance test indicate each device exert
oneself, reach 10,000, fresh water salt content less than 5mg/L,
meet using water quality requirement of the power plant .

13

4. Desalinization craft characteristic of Huanghua
power plantvapourPrepare sea waterHotpressure

Smoke thevacuumseawaterCondense

4 result MED-TVC desalinization device
technological process sketch maps

Brine

Fresh water

14

4. Desalinization craft characteristic of Huanghua
power plantTechnological characteristic of many result desalinization of low temperature ：z

The maximum temperature of brine is low at 70 ℃z

A series of level in charge of, spray, lower membrane evaporimeter connect inseries, assign, first evaporation temperature of results most high, reduce stepby step later.

z

Steam heat vaporizes in transferring to the hot sea water absorption tube thatis in charge of flowing outside, steam that produce introduce result the next asheat steam, evaporate and condense course produce high-quality fresh water
many times.

z

Release the vacuum system to discharge and evaporate the uncondensable gas
emerging in course.

z

The many results distillation technology of low temperature (MED +TVC) with
hot pressure, is one of the most energy-conserving methods in distillation law,most suitable for the desalinization factory and thermal power plant throughtransport way.
15

4. Desalinization craft characteristic of Huanghua
power plant
Technological characteristic of many result desalinization of
low temperature ：zz

The electric energy is consumed little, mainly utilize vaporization
latent heat of steam of low grade.
Heat the sea water (highest working temperature at the lowtemperature low at 70 ℃), the apparatus corrodes, forms the dirt
to lighten, apparatus dependability is high.

z

Sea water water quality has a good adaptability. The silt exceeds
standard in short-term, the device can still run normally, just needstrengthening and washing, will not exert an influence on theapparatus life-span.

z

The device is strong, water yield can be regulated between 50%110% of the specified output.

zPlant maintenance. Plant maintenance is similar to the power plantand congeal the vapour device, simple, availability is high, overhaul
and mainly clean every year, it nearly takes one week.
16

5．technological research of combined desalination plantwith power plant 10,000 ton-class low temperature many desalinization apparatus of result
employ, belong to the first time still at home, lie in ink Electricity Federation
produce technical application especially. In order to guarantee the security,
economical operation of the aircrew and desalinization device, electric organization,
China of country, launch water Electricity Federation produce low temperature
many result sea water technical application research work, make sometechnological research results, a large amount of research work is still in process.

Construction course of the first stage of desalinization
device of Huanghua power plant17

5．technological research of combined desalination
plant with power plantz

Carry on the electric water and unite the planning which produces
the overall system and apparatus selecting type to study, finish,
utilize domestic and 600MW steam turbine low-voltage to releasevapour carry on desalinization make feasibility research of ink on alarge scale, have chosen the suitable desalinization scheme.

z

Launch steam turbine pump heating power match of system, systemof vapour and desalinization of TVC-MED optimize and study, finish
the desalinization device to importing the accommodation research
work that the steam pressure changes, improve the adaptability
that the apparatus of desalinization changes to aircrew's load.

z

To the harbour special water quality condition in Huanghua, havechosen the high-efficient sea water treatment technology craft inadvance, the implementing effect is good, guarantee TVC-MED
desalinization device runs reliably.
18

5．technological research of combined desalination
plant with power plantz

Optimize and improve craft system and control procedure thatthesupplier

designs,

hasformedintactoperation

andmaintenance management software. Carry on desalinization
various

operating

mode

of

devicedebug,

until

TVC-MEDtechnological development accumulate experience in the future.
z

Control and study the antiseptic, scale control of the apparatus.

z

Launch domestic to hinder dirt pharmaceutical substitute theimport, hinder dirt pharmaceutical and strong research ofcomprehensive utilization of brine.

z

For reduce desalinization project make the investment, launchlowtemperature

many

resultdesalinization

technologicalproduction domesticization research work actively.

19

conclusion Thermal power plant in produce operate, needing alarge amount of fresh water, low temperature multieffect desalination technology main technology indesalination one of, can fully utilize low grade heat
energy of the power plant to produce and desalinize
water, solve power plant with the water supply in theplace, so has received the extensive attention.
 Launch desalinization of thermal power plant andtechnical research which water Electricity Federation
produced, to open up new power order, have important
realistic meaning, for promote of our country coastalsustainable development of regional economy, improve
the living standards of the people, the harmonious
society of comprehensive construction is significant.
20

21Day 2 Tuesday 16 October 2007
Session 7: Energy and Water Saving in Coal-fired Power Plant

Speech 2 US
Low-Risk and High-Return TIFItm Technology for Energy Efficiency
Improvement and Pollution Reduction

Dr. Linda Lin
Vice President
Asia/Pacific
FuelTech
USLow Risk and High Return TIFI™ Technology
for Improved Energy Efficiency
and Reduced Pollution

低风险、高回报的节能降污–
畅通节能法™
Dr. Linda Lin (林美珍)
APEC Clean Fossil Energy Seminar
October 15-17, 2007
Xi’an, Shannxi, P.R. China

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

COMPANY PROFILE - 公司简介

美国燃料技术公司 Fuel Tech, Inc.
北京福泰克环保科技有限公司
Beijing Fuel Tech Environmental Technologies Co., Ltd.

燃料技术公司Fuel Tech, Inc.: 是美国一家全球领先的科技开发和应用公司- A leading technology supplier based in the US.
专门从事大气污染控制及锅炉节能减排，包括烟气脱氮技术和提升锅炉能效、降低锅炉污染物排放，以及优化实际运行工程
的专业服务。Air pollution control and energy efficiency
improvement programs and power plant optimization services.

是美国纳斯达克(NASDAQ)上市公司（股票代码FTEK）。
Fuel Tech, Inc.

Technologies to enable clean efficient energy™

最完整的脱硝技术菜单-满足新建和改造及个别和总体排放要求:
畅硝™ (NOxOUT®) 系列 烟气脱氮技术

Most Complete Menu (NOxOUT®) on NOx Emissions Reduction
尿素

NO

N
O

N
O

N
O

New or Retrofit (NOxOUT®) Individual Unit or Total Emissions Reduction中国现有烟气脱硝项目
中国

Current China APC Projects -4 x830 t/h; 4x 200 MW NOxOUTULTRA® (Shijinshan and Gaobeidian)-华能高备店, 京能石景山
NOxOUT ULTRA®

4 x 600 MW NOxOUT® SNCR
(Ligang) 江阴利港 SNCR andNational Demo 2 x 600 MW
NOxOUT CASCADE®
(Kanshan) 中电投阚山混合法

Korea

3 4
BeijingJapan

21
Shanghai
Guangdong

TaiwanProject Sites
Hong Kong

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Ligang 4 x 600 MW Ultra Supercritical Units #5-8 -江阴利港 4 x 600 MW超超临界 SNCR•

Units 5 and 6 Commissioning Completed

五，六号机组已经试车调试完成•

NOx Baseline 350 mg/Nm3. 基线值350 mg/Nm3•

SNCR Achieved <200 mg/Nm3.
SNCR脱硝至<200 mg/Nm3•

SNCR ~45% NOx Reduction.
SNCR 脱硝效率~45%

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

NOxOUT ULTRA® Reduction – Huaneng Gaobeidian NOx Begins to be Reduced as Urea Solution is Injected华能高备店 830t/h -尿素注入 SCR 初期

Baseline
NOx基线值

Reduced脱硝至NOxFuel Tech, Inc.

Technologies to enable clean efficient energy™

NOx Reduction – Baseline: Green
Reduced NOx: Blue (Actual O2)
High NOx Reduced, 252 to <30 mg/m3 or 88%

Baseline
NOx基线值
Reduced脱硝至NOxFuel Tech, Inc.

Technologies to enable clean efficient energy™

TIFI™ PROFILE – TIFI™ 概述
节能降污的需求和目标
II. Problem Definition
问题的定义III. Technology Development 畅通节能法的发展
IV. Technology Merits
技术精华V.
Performance and Results 技术性能和结果
VI. Proven Value and ROI节能降污的价值和回收
I.

Needs and Goals-Low Risk and High Return -低风险、高回报的成熟科技

Conclusion

Fuel Tech, Inc.

结论Technologies to enable clean efficient energy™

Needs and Goals 节能降污的需求和目标 (cont’d 续)
Coal-fired Boiler Statistics from Recent Years

根据近年中国火电设备事故统计燃煤电厂锅炉情况:•

Boiler accidents accounted for 56% of the total.

锅炉事故占全部发电事故的56%，•

Boiler tube failures accounted for 64.2% of the boiler issues.

•

Excluding reasons from welding and material quality
problems, most boiler issues came from deposition, slagging,high and low temperature corrosion and erosion.

而锅炉四管爆破事故占全部锅炉事故的64.2%。

产生事故的原因除管材和焊接质量问题外，主要是由于锅炉积灰、结渣、高低温腐蚀、磨损引起。
Reference: Paper by Liu, C. W., Beijing Jingneng Co-gen Co.

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Needs and Goals 节能降污的需求和目标 (cont’d 续)•

The fouling costs include excess heat transfer surface area, extra
fuel, and maintenance costs.
沾污事故包括增添的热交换表面积、多加的燃料和维修费用。

•

86,400 Yuan (~11,000 USD) per megawatt for 100 and 200 MW
boilers at Changshan Power Plant studied.
在的锅炉研究发现,热交换率造成每一MW 86,400人民币的损失。

•

Costs due to utility boiler fouling are 10.008 billion Yuan RMB
without considering the costs due to product loss, which is about
0.11% GDP of China in 2000.
如果不计算发电损失,电站锅炉沾污造成热效损失占全国生产毛额
的GDP的0.11% 。

Z. M. Xu 1, S. R. Yang 1, S. Q. Guo 2, H. Zhao 3, B. Qi 3, Z. B. Zhang 1 1Northeast China Institute of ElectricPower Engineering, Jilin City, Jilin Province 132012, China; 2Institute of Engineering Thermophysics, Chinese Academy of
Science, Beijing 100080, China; 3Huaneng Dalian Power Plant, Dalian 116100, China

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Problem Definition: Fireside Problematic Triangle

问题的定义
Slagging is a process from: 结焦就是由沾污 (Deposition)、
共晶共融 (Eutectic) 和粘附 (Adherence) 三个过程形成的

FOULING沾污

CORROSION
高低温腐蚀

SLAG
结焦

EROSION 磨损
Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Most Likely Fireside Problem Areas

最可能出现问题之处Convection Pass and Section –Pendant, Superheaters对流受热區-后屏、过热器Radiant Heat Section - Reheater辐射传热區-再热管
Water-Wall Zone 水冷壁管區
Burner Zone
燃烧器周围
Bottom Slopes
斜坡底处

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Pendant Section 后屏區|Tube leaks from clinker falls

焦块堕落造成的炉管破裂|

Dripping and falling slag tolower slope tubes

焦块堕落到斜坡底处|Loss of heat transfer减少了热交换效率

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Convection Pass 对流受热區|

Limiting factors

受限因素zHigh furnace exit
temperatures

高的炉膛出口温度z ID fan stall影响引风机出力|

Increased sootblowing results inerosion 增加的吹

灰造成磨损Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Slag / Clinker 焦块
Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Increased Cost Due to Energy Efficiency
Loss, Stop and Go Power Generation,and Increased O&M Cost

在能效损失的同时,停止和间断性
的发电, 增加很多操作和维修费用

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Safety

安全

Unpredictable Time Bomb:
Fallen slag damaged boiler
bottom, caused shutdown.

不可预兆的定时炸弹:结焦渣物堕落砸的风险。
炉膛水冷壁、对流受热面结焦，严重的掉焦反正发生锅炉
灭火，被迫降锅炉出力，甚至
于停炉的现象。
Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Technology Development 畅通节能法™的发展

80+ years offireside treatment
experience

Fuel Tech, Inc.

Advanced boiler injection
design by NOx reduction
SNCR

Technologies to enable clean efficient energy™

标靶科技 “Targeted”
Tech: Never thought
achievable
technology results

TIFI™ - Targeted In-Furnace Injection™ Technology[ FUEL CHEM® 畅燃药剂 ™系列 ]畅通节能法™ - 节能减排的标靶式炉内喷射科技
TIFI™ technology is an innovative hi-tech approach that prescribes postcombustion “targeted” treatment.

畅通节能法(TIFI)是一种燃烧后处理工艺。融合计算机模拟高科技、联合虚拟和真实的模拟模型，把有效的化学药
品、标靶性的喷射到锅炉系统需要增加热交换的位置,精确
的控制热交换表面的清洁度、来提升燃烧热效率和节省燃料以及减少污染排放。

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

“Targeted” TIFI™ Approach
TIFI™标靶式炉内喷射科技|

Custom tailored strategy for each unit针对客户的锅炉和燃料特性个案而
提供有目标的量身定造|

90%+ goes to treat “Targeted” areas

百分之九十以上达到标靶部位|

Result: excellent economics & performance

结果是特佳的经济和性能效益
•Around 100 successful cases
在全球有近百个成功案例

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Problem
Areas

PreciseChemicalInjection

3D Visualization – Precise Distribution Technology

三维目视-精确的注射科技

Over 500 furnace injection experiences
Fuel Tech, Inc.

已在全球成功运行了几百炉内喷射个工程业绩Technologies to enable clean efficient energy™

Zone of Predicted Slag Formation (Ash Fusion Temperature Zone)
Design/Shenhua Blend Coal (神华混煤)Softening T 软化灰熔点 = 1200°C

Side View
Fuel Tech, Inc.

Front View

Technologies to enable clean efficient energy™

Zone of Predicted Slag Formation (Ash Fusion Temperature Zone)
Inspect Coal/Huainan Coal(淮南煤) Softening T 软化灰熔点 = 1400°C

Side View
Fuel Tech, Inc.

Front View

Technologies to enable clean efficient energy™

Performance and Results 技术性能和结果Fossil fueled plants, Industrial applications, and Municipal
Solids Waste (MSW) and Waste-to-Energy (WTE) Plants.

畅通节能法应用于使用化石燃料(煤、石油)和垃圾燃料的电力设施、工业锅炉和垃圾焚烧设施上。
Applicable when using high volatility and high heat value coals.
如果燃用挥发分和发热量过高的优质煤种，也会减少锅炉炉膛结焦。
New units in addition to retrofit.
如果是新建机组，也会减少锅炉炉膛结焦。
Results will be amplified when using low-quality fuels.
如果是劣质燃料，性能对比放大。

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Seeing is Believing眼见为实
炉 内 结 焦 处 理
前 后 对 比处 理 前 后 烟 气
排 放 的 对 比

炉管 处理前Tube Before TIFI

处理后8个小时
8 Hours after TIFI烟囱排放 Stack:处理前处理后
Before & After TIFI

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

处理后24个小时
24 Hours after TIFITIFI™ Results – SO3 Mitigation
TIFI™ 对SO3 减少的性能
400 MW Residual Oil Plant
Hybrid TIFI Trial
14

12

SO3 PPM

10

8

6

4

2

0
1

2

3

4

5

6

7

8

9

10

11

Baseline

1:40001:2000

1:1000Baseline

1:40001:2000

1:10001:30001:30001:3000Fuel Tech, Inc.

Technologies to enable clean efficient energy™

TIFI Result – Ash pH

No. 6 Residual Fuel Oil
Wall Fired 400MW TIFI Hybrid Test

12

1:3000June 25

1:3000June

1:3000June 1110
Ash pH灰份 pH 值1:3000June 25

8
6No
Injection
June 6

4

No Injection
June 3

StartedInjection
1:4000June 5

1:3000June 10

No Injection
June 17

No Injection
June 18

No Injection
June 19

8

9

2
0
1
Fuel Tech, Inc.

2

3

4

5

6

7

Technologies to enable clean efficient energy™

10

11

TIFI
HYBRID
Result– withCombustion
Catalyst –
Oil
Fired
Power
Plant
Catalyst
Performance

TIFI 混合法加燃烧催化剂18

O p acity (% ), 6 m in u te averag e

16
Catalyst @ 1:2000

14
12
10
8

Catalyst turned off

6
4

Catalyst @ 1:4000

O2 turned down

2
0
0.53

0.54

Fuel Tech, Inc.

0.05

0.07

0.08

0.09

0.11

0.12

0.13

0.14

0.15

0.16

Technologies to enable clean efficient energy™

0.17

0.19

0.2

0.21

0.22

Infrared Camera-Port Monitoring 红外线的监测对比
B & W 475 MW Hugo Station unit - Port #4 represents the center most section of the boiler, and istraditionally the most problematic.

No TIFI™ 无使用TIFI™ 时

Fuel Tech, Inc.

Using TIFI™ 使用TIFI™ 时

Technologies to enable clean efficient energy™

Before and After TIFI™ 处理前对比处理后

Slag Prior to TIFI处理前

Deposit After TIFI
处理后

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

7/
21
/2
7/ 0 05
28
/2
0
8/ 05
4/
2
8/ 00 511
/2
8/ 0 0518/2
8/ 0 05
25
/2
0
9/ 05
1/
20
9/ 0 58/2
9/ 00 515
/2
9/ 0 0522/2
9/ 0 0529/2
10 0 05/6/
10 20 0
/1
5
3/
2
10
0
/2 05
0/
10 2 00
/2
5
7/
20
0
11
/3 5
/2
11
0
/1 05
0/
11 2 00/1
5
7/
11 2 00
/2
5
4/
20
12
0
/1 5
/2
12 0 05/8/
12 20 0/1
5
5/
12 2 00/2
52/
12 2 00
/2
5
9/
20
05

MW

Load Sheds Reduced from Nightly to Weekly -每晚急降符合减焦变成每周一次
Before TIFI™

900

Fuel Tech, Inc.
LOAD PROFILE

处理前

DATE
MW

Technologies to enable clean efficient energy™

After TIFI™
处理后

830

760

690
Began Injecting on 10/6/05

620

550

480

410

340

Comparison of Average MW: UNIT 3 vs. UNIT 4 (TIFI Treated)两个同样烧PRB煤的900MW对比
Twin 900 MW Units

处理后UNIT 4-TIFI Treated

1000

900

Load (MW)

800

700

600

500

400

未处理UNIT 3 – No TIFI
300
1

4

7

10

13

16

19

22

25

28

31

34

37

40

43

46

49

52

55

58

61

64

67

70

73

76

79

82

85

Hour of Run
Unit 4 Load

Fuel Tech, Inc.

Unit 3 load

24 per. Mov. Avg. (Unit 3 load)

24 per. Mov. Avg. (Unit 4 Load)

Technologies to enable clean efficient energy™

88

91

94

Before and After TIFI™ 处理前对比处理后
Pendant andSuperheater
后屏和过热器

Before (top 2)
and处理前
After TIFI
处理后

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Typical Proved Benefits 典型可证明的的获益增加热效率,高的能量输出增加锅炉系统稳定和可用性
减少SO3和硫酸腐蚀和磨损

0.5-1%可高至 3%以上
测量的参数稳定

降低NOx和SO3/SO2排放
5-10%NOx, <5 ppm SO3
减少飞灰和烟囱中的未燃碳
1-5%可高至 10%以上
扩展燃料选择范围
更多的燃煤购买选择低运行维护费用
较少的CO2排放或减少燃料用量增加可靠度和发电量延长设备寿命空气污染物减排
增加能量效率烧低价格的煤

修理停机频率减少
水、蒸汽、吹灰、清洁联合国气候变化 京都协议CER排放信用

发电量的增加获益强大并且减少了空气污染的排放量
Fuel Tech, Inc.

Technologies to enable clean efficient energy™

MW Gains Seen in Various MW Units

各种不同机组看到的发电的增加量
900
800
700
600
500
400
300
200
100
0

BeforeFuel Tech, Inc.

After

BeforeAfter

BeforeAfter

BeforeTechnologies to enable clean efficient energy™

After

BeforeAfter

Real Power Generation and Reliability Increase
Average Evaporative Heat Absorption Contribution to发电量和可靠度增加
Total Heat Absorption

Percent of Total Heat Absorption

39(GMW > 300 Filter Applied)
TIFI Initiation
Dosage Increase
Injectors Added
DosageIncreased
初用TIFI™
剂量增加

38.5

Stop TIFI
Shutdown,
Dosage=0
停止TIFI

Average = 38.2

38
37.5

Average = 37.4

37
Average = 36.9

36.5

11
/
11 8 12 /21/
12 2/0/1 5 12 0/0/1 5 12 2/0/1 5 12 4/0/1 5 12 5/0/2 5 9
1/ /05
10 1/ /06
12 1/ /06
16 1/ /06
19 1/ /06
21 1/ /06
28 /0
2/ 6 2/0
2/ 6 6
2/ /06
10 2/ /06
15 2/ /06
19 3/ /06
14 3/ /06
16 3/ /06
19 3/ /06
25 /0
6
-

36

Between Shed Period Start Date

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Real Power Generation and Reliability Increase发电量和可靠度增加
TIFI’s Benefit
使用TIFI™效益

使用 TIFI

TIFI®

無使用 TIFI

使用 TIFI

Proven Value and ROI 节能降污的价值和回收
- Low Risk and High Return - 低风险、高回报的成熟科技

SYSTEM DEPENDENT ACCUMULATIVE TIFI™ BENEFITS:
各个机组情况不一 、 累积性的利益 :1. EFFICIENCY GAIN (提升能效和节能)
2. ENVIRONMENTAL BENEFITS (环保效益)
3. MAINTENANCE AND OPERATIONCOST SAVINGS (节省操作和维修费用)
4. SAFETY (安全)Fuel Tech, Inc.

Technologies to enable clean efficient energy™

应用 TIFI™ 系统可节省的操作和维修费用
500 MW 机组 – Powder River Basin (PRB)煤
能量效率费用10每年净节省能源费用
= 四百十万美元美元 (百万 )8

TIFI项目

6

热效率损失

4

清理

2

吹灰

0

损失MW数
没有用 TIFI有用 TIFI运行情况
Fuel Tech, Inc.

Technologies to enable clean efficient energy™

FUEL CHEM® TIFI™RETURN-ON-INVESTMENT EXAMPLES
460 Mw

850 Mw

150 Mw

850 Mw

625 Mw

T-Fired

T-FiredWall-Fired

Wall-Fired

Wall-Fired

Utah Coal

PRB Coal

PRB/Eastern

PRB Coal

PRB Coal

1,825
200
12
6
$2,043

2,000
300
18
15
$2,333

545
60
5
10
$620

3,000
325
18
15
$3,358

1,400
150
9
12
$1,571

Deration
Deslagging
OutageFireside Cleaning Expenses

750
400
600
50

9000
700
400
125

900
350
0
15

5000
500
255
90

1800
500
200
60

Thermal Efficiency Improvement
Reduced Sootblowing
Medium Savings
Maintenance Savings
Hardware Savings
Steam Tube Replacement
Corrosion/Erosion
Falling Slag Damage
ID/FD Fan Power
Alternate Fuel Source
Cold End Corrosion
Air Heater
Ductwork
Stack
Worker Safety (priceless)
Sub-Total

100

1000

300

800

600

200
70
50

370
130
95

0
0
0

370
130
100

300
100
80

600
250
2
1,400

1100
460
4
0

180
75
1
450

1100
460
4
0

840
350
3
0

0
0
0

0
0
0

50
25
25

0
0
0

0
0
0

$4,472$13,384$2,371$8,809$4,833Customer Net Savings$2,429$11,051$1,751$5,451$3,262Customer ROI (%)

219

502

382

262

308

Program Costs
ChemicalDilution Water
Compressed Air
Tank Rental
Sub-Total

Program Savings
Purchased/Alternate Kwhr's

Fuel Tech, Inc.

All costs and savings are $x1000/year

Technologies to enable clean efficient energy™

Coal Consumption per kW-hr Generation －A Critical Indicator for “Energy Savings and Pollution Reduction”“供电煤耗”: 考察节能降耗的一个重要指标
Capacity

Accumulative % - Coal Consumed per kw-hr Generation

容量
（MW）

每千瓦时上网电所消耗的标准煤的累积比例 %< 320 g700-100090%

500-600400< 330 g

< 340 g< 350 g

50%

81%

90%

60%

93%

< 360 g< 370 g

300

85.7%

90%

200

0.6%

24%

48%

135-150

31%

63%

125

6%

26%

China Electricity Council on the Grid Data Based on 241 Power Generating Units Referencing the “Standard” Coal of 7000 Kcal.
火电分会:发电机组煤耗统计(241台机组): 每千瓦时上网电所消耗的标准煤(7000 Kcal或 29.27兆焦MJ )的量

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Fuel Caused Heat Rate Calculation Problems

燃料热量灰份成分不一对计算上的困扰

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Heat Rate and Emissions Improvement
TIFI provided 3% heat rate increase and
13% reduction in a US EPA Toxic Release Report

一案例增加了 3% 热效和减少 13% 了的污染物排放∑n units
Existing Unit
Heat Rate

Total
Heat
Rate

Heat rate improved isequivalent or bigger
than that by a new unit

Total Heat Rate
Improvement by
TIFI

Heat Rate &Emissionsof New Unit

TIFI Improvement
Heat Rate扩建机组使用创造出的热效污染物排放=整厂排放较原来一样或更低Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Local 223,
St. Clair, Michigan
Utility Workers Union of America, AFL-CIO
April 2, 2007

Proof of Satisfied
Customers

TIFI™满意顾
客的公证

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Conclusion 结论

在提升锅炉能效及节能减排方面:公司拥有
Fuel Tech
的 TIFI™
FUEL CHEM®
专利技术，致力于实现锅炉效率的最大化、设备寿命最长化和停机维
修时间最小化，可以有效降低甚至彻底消除结焦、结垢、腐蚀等问题，大大提高锅炉效能，增加发电量或减少
燃料消耗，增加燃料的
使用灵活度或燃烧劣质
燃料，并且可以同时减少氧化氮、氧化硫和烟
囱不透光、未燃碳和二氧化碳排放。
Technologies to enable clean efficient energy™

Fuel Tech, Inc.

Conclusion 结论
Energy Efficiency Improvement with Less Air Pollution
Using proprietary TIFI™ technology, Fuel Tech has demonstrated
in numerous commercial applications that FUEL CHEM®
Program can: 畅通节能法已经有近百个业绩|

Near ZERO Capital Investment 几乎零的先投资|Very LOW Risk to End-User Power Plant 很小的风险|

Extremely High Upside Return 很高的回报|Fuel Flexibitiy (Type, Cost, Source) 能使用多样化的煤种|

Performance Demonstrated before Long-term Purchase 性能

在长期合同前已经验证

Fuel Tech, Inc.

Technologies to enable clean efficient energy™

中国电话: 86- 10- 8487 1472～1477
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Fuel Tech, Inc.

Technologies to enable clean efficient energy™

Day 2 Tuesday 16 October 2007
Session 7: Energy and Water Saving in Coal-fired Power Plant

Speech 3 PR China
Evaluation of Energy Consumption and Analysis of Energy Saving
Potential in Coal-fired Power Plants

Mr. Yu Xingying
Deputy Director
Utility Technical Supervision
Thermal Power Research Institute (TPRI)PR China于新颖教授级高级工程师，现任西安热工研究院技术监督部副主任，硕士研究生导师。
1982年1月毕业于西安交通大学，83年至今一直任职于西安热工研究院，1994年～1995年
在德国埃森大学从事煤气化联合循环（IGCC）发电技术研究。
担任全国汽轮机标准化委员会委员兼副秘书长，中国动力工程学会电站辅机分专委会委员，《电站辅机》杂志编委。中国电机工程学会的科技专家。
主要从事火电厂汽轮机及其辅助设备的性能分析、故障诊断、状态检修、节能降耗方面的研究。
研究成果有：电力部大功率高转速液力偶合器的开发研制，部控项目大型火电机组现状及
发展前景研究，国家95攻关项目IGCC关键技术研究，部控项目国产引进型300MW机组降耗
措施研究，高/低压加热器性能分析与故障诊断，旋膜式热力除氧器的设计研究，提高凝汽器性能与真空度的分析研究，汽轮机冷端系统运行优化研究，IGCC电厂系统优化设计研究，火电厂状态检修方面的研究。
近期的研究内容：国产亚临界600MW机组安全性和经济性评估，超超临界1000MW机组安全性和经济性分析，发电机组大修后评估研究，火电厂技改和重大项目后评估研究，华能新建机组能耗评估和污染物排放研究，国华机组经济性综合研究，华能节能评价体系研究，
发电机组设计值核准研究等。
负责编制的电力行业标准有：DL/T 932-2005《凝汽器与真空系统运行维护导则》，《表面式凝汽器运行性能试验规程》，《火电厂除氧器运行性能试验规程》。
荣获省部级科研成果奖三项，市局级成果奖近三十项。公开发表论文40余篇。

YuXinying
Senior Engineer Yu Xinying, male, was born in Oct. 1055. Currently he is serving as the Vice Director ofTechnological Supervision Department of Xi’an Thermal Power Research Institute.
He graduated from Xi’an Jiaotong University in Jan. 1982, and has worked since then in Xi’an TPRI. From1994 to 1995, he was involved in IGCC power generation technologies at Duisburg-Essen Universitaet inGermany.
Currently he is a member as well as Vice Secretary General of the National Standardization Committee of
the Designing, Making, Testing and Rating of Steam Turbines, a member of Power Station Auxiliary
Equipment Branch under China Society of Power Engineering, editor of “Power Station Auxiliary
Equipment”, and a scientist of China Society of Electric Engineering.
His primary fields of interest include performance analysis, fault diagnosis and maintenance of steam
turbines and other auxiliary utilities in coal-fired power generation plants, energy saving and energy
conservation, etc.
His major achievements made in the past were as follows: research and development of the big-power highspeed hydraulic turbo coupling funded by Ministry of Electric Power, a ministerial-level research on thepresent and future utilization of the large-scale generating sets for coal-based power generation, a state-levelproject on key technologies for IGCC, a ministry funded project on energy saving for 300 MW steam turbine(imported type) equipment and system. In addition, He has dedicated himself to the research on theperformance and fault diagnosis of high/low pressure heaters, the study and design of turning pellicle
heating power, the enhancement of condenser performance and its degree of vacuum, the running
optimization for turbine cold junction system, the design and optimization of systems in IGCC power plants
and inspection of operations in coal-fired power plants.

YuXinying
His recent studies include: evaluating of safety and economy of the home-made sub-critical 600
MW generating –set and analysis of safety and economy of the supercritical 100 MW generatingset, evaluating generating set after major repairs, evaluation of the technological transformation andkey projects in coal-fired power plants, studies on emission of pollutants and evaluation of energy
consumption for the newly started up generating set in Huneng Power International, Inc,
comprehensive studies on the economy of generating set in Guohua Electric Power Company,
research on the standardization of design for generating sets.
He presided over the formulation of the standardizations for the electric power sector, including
DL/932-2005 “Guide and Principle for the Operation and Maintenance of Condenser and Vacuum
System” , “Regulations for the Testing of Operation and Performance of Surface Condenser”, and“Rules and Regulations for the Testing of Operation and Performance of De-aerator in Coal-fired
Power Plants”.
He has won 3 provincial-level scientific research awards and nearly 30 municipal-level awards
with a total of 40 articles published in academic journals.

火电厂能耗评估与节能潜力分析
Energy loss evaluation and energy-saving
potential analysis for coal-fired power plant

西安热工研究院

Thermal Power Research Institute于新颖

Xinying yu

背景 • Background• 至2006年底，全国投运的超临界600MW机组共 38 台；
There were thirty-eight 600MW supercritical units in China
till the end of 2006.

• 2004年～2006年投产超临界600MW机组32台；

Thirty-two 600MW supercritical units had put into
production from 2004 to 2006.

• 投产后基本达到设计煤耗水平的仅 7 台；

Only seven units reached the designed coal consumption rate.

背景 • Background• 汽轮机考核试验热耗大于设计值100kJ/kWh的约 21台；
About twenty-one units’ performance test heat rate arehigher than designed by 100kJ/kWh.

• 投运两年来,由于各种原因造成每年两次以上非停的有 15
台；
Fifteen units had two unplanned outages every year in thepast two years.

• 目前在建的超临界600MW机组46台。

Forty-six supercritical units are under construction.

背景 • Background截至2007年7月31日：
Till 2007-7-31,• 已投运600MW超临界机组55台，1000MW超超临界机组4台。
Fifty-five 600MW supercritical units and four 1000MW ultra
supercritical units had been put into production.
z 已订货600MW超临界机组210台，600MW级超超临界机组25
台，1000MW级超超临界机组42台。
Two hundreds and ten 600MW supercritical units, twentyfive 600MW and forty-two 1000MW ultra supercritical units
are ordered.

期望 • Goal

研究机组经济性指标、运行可靠性水平、污染物排放与环保设备性能、以及系统设计、设备选型、产品质量、安装调试等。
Study the thermo-economics, reliability, emission , performanceof environmental protection equipments, system design, equipment
selection, equipment quality , setting and unit regulation and so on.
通过分析机组效率、煤耗、厂用电率、污染物排放等主要技术经济指标的实际水平与设计水平的差距，明确造成差距的主要原
因和存在的问题，提出提高机组经济性和环保性能的方法和途
径，促进新投产机组实现资源节约型企业标准的目标，为后续工
程建设提供经验。
Point out the problems by analysis the distance between the realand designed thermo-economics , unit efficiency, coal consumption
rate, power consumption rate and emission. Give the way to
improve the thermo-economics and environmental protection.
Promote the standard of environment-friendly corporation andprovide the reference for the rest units.

主要内容 • Main Content








新投产机组能耗现状
Energy loss level of new units
影响经济性的主要因素
Main factors influence the thermo-economics节能降耗工作重点
Key work to improve the energy-saving
辅机选型与运行情况
Auxiliary Equipment selection and operation
工程建设启示
Enlightenment from construction
日本电力之借鉴
Reference from Japan几点建议
Several suggestions

1. 新投产机组能耗现状Energy loss level of new units

A
厂

B
厂

C
厂

负荷率
Load Rate

锅炉效率BoilerEfficiency

汽轮机热耗率Turbine Heat
Rate

发电煤耗
Coal Consumption
rate of electricity
generation

供电煤耗
Coal Consumption
rate of electricity
supply单位 Unit%%kJ/kW.hg/kW.hg/kW.h设计 designed

100

93.87

7522

276.5

292.34

试验 test

100

94.22

7675

281.1

295.5

运行 operation

78.33

92.53

8009.17312.21327.83设计 designed

100

93.66

7516

276.9

295.9

试验3 test

100

93.67

7668

286.8

300.6

运行3 operation

80.4

306.1

324.3

试验4 test

100

289

299.9

运行4 operation

81.8

309.1

324.6

设计 designed

100

280.53295.95

运行1 operation

80

299.68316.07

运行2 operation

78

294.26309.68

93.79

93

7742

7522

A电厂主要经济指标• Main thermo-economics index of A power plant设计值designed

性能试验
Test
(THA)

2005年累计值
2005 Operation

2006年1～8月累计值
2006-1~2006-8 Operation

锅炉效率•Boiler Efficiency (%)

93.87(BRL)

94.22

93.8

92.53

汽轮机热耗率•Turbine Heat Rate (kJ/kW.h)7522(THA)

7675.07861.28009.17发电煤耗• Coal Consumption rate ofelectricity generation (g/kW.h)

276.5

281.1

323.64312.21项目

脱硫厂用电率• Power consumption rateof desulphurization (%)

0.85

生产厂用电 (含脱硫) • Powerconsumption rate (desulphurization
included) (%)

4.37

4.66

综合厂用电率• Integrated Powerconsumption rate (%)

5.41

4.86

4.48

4.77

供电煤耗• Coal Consumption rate ofelectricity supply (g/kW.h)292.34295.5

338.80327.83

A电厂汽轮机缸效率• Turbine cylinder efficiency of A power plant
单 位
Unit

设计值
designed(4VWO)

考核试验
Performance Test
(4VWO)

高压缸效率 • High Pressure Cylinder
Efficiency

%

88.58

87.98

-0.6

试验中压缸效率• I. P. Cylinder
Efficiency in Test

%

92.60

91.73

-0.9

真实中压缸效率• I.P. Cylinder
Efficiency in Operation

%

91.89

89.23

-2.7

低压缸效率• Low Pressure Cylinder
Efficiency （UEEP）

%

91.59

86.34

-5.3

高中压缸间汽封漏汽量 • GlandSteam Leakage Between H.P. and I.P.
Cylinders

t/h

19.8

44.2

24.4

差别
DistanceB电厂主要经济指标• Main thermo-economics index of B power plant
主要指标
Main Index设计值
designed

负荷率•Load Rate

3号 • #3 unit

4号• #4 unit

考核试验Performance Test

实际运行
Operation

考核试验Performance Test

实际运行
Operation

100

100

80.4

100

81.8

锅炉效率•Boiler Efficiency

93.66

93.67

汽轮机热耗率•Turbine Heat Rate

7516

7668.0生产厂用电•Power Consumption
Rate

4.5 不含脱硫

4.57 含脱硫

综合厂用电(含脱硫)•Integrated
Power Consumption Tate

7829.0

5.69

4.66(desulphurization included)发电煤耗• Coal Consumption

rate of electricity generation
供电煤耗•Coal Consumption

rate of electricity supply

276.9

286.8

306.1

309.1

295.9

300.6

324.3

324.6

B电厂汽轮机缸效率• Turbine cylinder efficiency of B power plant单位设计值
designed(4VWO)

3号考核试验
#3 Unit Performance
Test(4VWO)

4号考核试验
#4 Unit Performance
Test(4VWO)

高压缸效率 • High Pressure
Cylinder Efficiency

%

88.58

86.12

87.11

试验中压缸效率• I. P. Cylinder
Efficiency in Test

%

92.60

91.98

91.18

真实中压缸效率• I. P. Cylinder
Efficiency in Operation

%

91.89

91.36

91.42

低压缸效率• Low Pressure
Cylinder Efficiency （UEEP）

%

91.59

87.4

84.4

高中压缸间汽封漏汽量 •Gland-Steam Leakage Between
H.P. and I.P. Cylinders

t/h

19.8

32

/

试验工况

C电厂机组煤耗分析• Coal consumption rate analysis for C power plant设 计
designed

考核试验Performance Test

检修后试验
Test after Overhaul

实际运行Operation

#1

#2

#1

#2

#1

#2

发电煤耗•CCREG

280.53287.98285.86294.55291.1

299.68294.26

供电煤耗•CCRES

295.95301.08298.55308.21303.8

316.07309.68#1 Unit#2 Unit

运行比考核发电煤耗高
Distance between operation and test of
CCREG

11.7

8.4

运行比考核供电煤耗高Distance
between operation and test of CCRES

14.99

11.13

运行比设计发电煤耗高
Distance between operation anddesigned of CCREG

19.15

13.73

运行比设计供电煤耗高Distance between operation anddesigned of CCREG

20.12

13.73

• C电厂1号机组设计-试验-修后-运行煤耗比较
Coal Consumption Rate Compare between designed, test, after overhaul andoperation of C power plant unit 1（g/kw.h）316.07

320

设计
考核
修后
实际

308.21

310
300
290

299.68294.55287.98301.08295.95280.53

280
270
260

发电煤耗率

供电煤耗率

• C电厂2号机组设计-试验-修后-运行煤耗比较
Coal Consumption Rate Compare between designed, test, after overhaul andoperation of C power plant unit 2（g/kW.h）
320
设计
考核
修后
实际

309.68303.8

310298.55294.26300

295.95291.1
285.86290

280.53

280
270
260

发电煤耗率

供电煤耗率

机组能耗水平 • Energy Loss Level of New Units
A电厂3号机组考核试验的发电煤耗较设计值高6.2 g/kW.h，2006
年1～8月份实际运行的发电煤耗较设计值高35.6 g/kW.h。
Test coal consumption rate of A power plant unit 3 is higher thandesigned by 6.2 g/kWh, operation is higher than designed by
35.6g/kWh in the early eight months of 2006.
B电厂3号、4号机组考核试验的发电煤耗较设计值高10 g/kW.h、
17 g/kW.h，实际运行的发电煤耗较设计水平差距约30 g/kW.h。
Test coal consumption rates of B power plant unit 3 and 4 arehigher than designed by 10 g/kWh and 17g/kWh , operation ishigher than designed by about 30g/kWh.
C电厂1号、2号机组：考核试验的发电煤耗较设计值高7 g/kW.h、
5 g/kW.h，实际运行发电煤耗较设计值分别高19.15 g/kW.h和
13.73 g/kW.h。
Test coal consumption rates of C power plant unit 1 and 2 arehigher than designed by 7g/kWh and 5g/kWh , operation is higher
than designed by 19.15g/kWh and 13.73g/kWh.

2. 影响经济性的主要因素
Main factors influence thermo-economics• 影响因素Influence factors• 能耗分析
Energy loss analysis• A电厂影响机组经济性的主要因素
Main factors influence the unit thermo-economics of A power plantz主蒸汽、再热蒸汽参数偏低(主汽压z 汽轮机通流部分效率低；低3.13MPa）；
Low cylinder efficiency
Main steam and reheat steamz 机组负荷率低；parameter low. (main steam pressure
Low load rate
lower by 3.13MPa )z 机组真空下降（低2.21kPa)；
Low vacuum (lower than 2.21kPa) z锅炉排烟温度高（7 ℃ ）；Exhaust gas temperature high.
z 热力系统阀门内漏；(by 7 ℃)
Thermal system valve inner-leakage
z燃料中石子煤量大（石子煤的热值z 最终给水温度降低(17℃)；
Feed-water temperature drop (by 17 20MJ/kg ）。
Poor quality coal. (Calorific Value℃)z 再热器减温水流量增加(19~30t/h)； 20MJ/kg)
Attemperating water flow ofreheater increase (by 19~30t/h)

A电厂机组能损分析
Energy loss analysis for A power plant影响因素•Influence Factors

单位•Unit单位

与设计值之差Compare withdesigned

高压缸效率 H.P. cylinder efficiency

%

-0.6

0.3

中压缸效率 I.P. cylinder efficiency

%

-2.7

1.0

低压缸效率 L.P. cylinder efficiency

%

-5.3

7.0

排汽压力 Exhaust steam pressure

kPa

2.2

5.0

负荷率 Load rate

%

-15

5.0

系统泄漏 System leakage

t/h

10

1.9

t/h

24.4

0.9

t/h

25

0.9

HP-IP漏汽 Gland-Steam Leakage Between H.P. and I.P.
Cylinders

再热减温水流量 Attemperating water flow of reheater
加热器性能 Performance of heat供电煤耗变化量
Variance of CCRES g/kW.h0.3

主蒸汽压力 Main steam pressure

MPa

3.13

0.783

主蒸汽温度 Main steam temperature

℃

2.33

0.256

再热蒸汽温度 Reheat steam temperature

℃

1.82

0.101

最终给水温度 Feed water temperature

℃

17.24

1.433

排烟温度 Exhaust gas temperature

℃

7

0.7

入炉煤热值变化 Changing of coal heat value

kJ/kg

24

0.3

石子煤量（7、8月份） Poor coal amountt/月

1600/2158

3.38

合 计 Total

29.25

高
压
缸
效
中
率
压
缸
效
率
低
压
缸
效
率
排
汽
压
力
负
荷
率
系
统
泄
漏
HP
IP
再
漏
热
汽
减
温
水
流
量
加
热
器
性
主
能
蒸
汽
压
主
力
蒸
汽
温
再
度
热
蒸
汽
最
温
终
度
给
水
温
度
排
入
烟
炉
温
煤
度
热
值
变
化
石
子
煤
量

影响供电煤耗率（g/kWh）A电厂3号机组能损分析结构图

Energy loss analysis figure for unit 3 of A power plant

8

7

6

5

4

3

2

1

0

• B电厂影响机组经济性的主要因素
Main factors influence the unit thermo-economics of B power plantz 汽轮机通流部分效率低；Low cylinder efficiencyz 机组负荷率低；Low load ratez 机组真空下降（低1.2 kPa)；
Low vacuum (decrease 1.2 kPa)z 热力系统阀门内漏；
Thermal system valve inner-leakagez再热器减温水流量增加(12~20t/h)；
Attemperating water flow of reheater
increase (by 12~20t/h)z锅炉排烟温度高（112 ℃ /140
℃ ）；Exhaust gas temperature high.
z系统补水率高；Water makeup rate on the high sidez煤质变化影响。Poor quality coal.

B电厂机组能损分析
Energy loss analysis for B power plant设计值Design影响因素
Influence Factor

影响煤耗
Variance of CCRES （g/kW.h）运行数据Operation
3号机组
Unit 34号机组Unit 4汽轮机缸效率, Cylinder Efficiency

3号机组
Unit 34号机组Unit 47.1

10.5

机组负荷率，Load Rate, %

100

80.4

81.8

6.0

6.0

凝汽器真空，Vacuum,

96.8

95.14

95.14

3.67

3.67

1.9

1.9

0.8

0.8

0.7

0.7

kPa

系统泄漏, System leakage
HP-IP漏汽,Gland-Steam Leakage Between
H.P. and I.P. Cylinders, t/h

7.5

32

再热器减温水量， Attemperating waterflow of reheater ，t/h

0

10

10

机组补水率， Water makeup rate ，％

0

2.5

1.3

1.5

0.78

排烟温度，Exhaust gas temperature，℃

112

136.7

143.4

2.47

3.14

入炉煤热值变化， Changing of coal heatvalue , kJ/kg

0

145

145

1.9

1.9

26.04

29.39

合 计 TotalB电厂能损分析结构图
Energy loss analysis figure for B power plant
对煤耗率的影响（g/kW.h）

12

3号机组
4号机组

10
8
6
4
2

排
烟
温
度
煤
热
值
变
化

HP
-I
P漏
汽
再
热
器
减
温
水
机
组
补
水
率

系
统
泄
漏

汽
轮
机
缸
效
率
机
组
负
荷
率
凝
汽
器
真
空

0

• C电厂影响机组经济性的主要因素
Main factors influence the unit thermo-economics of C power plantz 汽轮机通流部分效率低；Low cylinder efficiencyz 机组负荷率低；Low load ratez 机组真空下降（低0.5kPa)；
Low vacuum (lower than 0.5kPa)z 热力系统阀门内漏；
Thermal system valve inner-leakagez再热器减温水流量增加(2~22t/h)；
Attemperating water flow of reheater
increase (by 2~22t/h)
z高压缸至中压缸轴封蒸汽流量大(1.4↑2.8%,2.5 ↑ 4.8%)
Gland-steam leakage between H.P. and
I.P. cylinders high.
z小汽轮机用汽流量(多15t/h)
Small turbine steam quantity highC电厂机组能损分析
Energy loss analysis for C power plant影响因素
Influence Factor

对热耗率的影响（kJ/kW.h）
Variance of Heat Rate对供电煤耗的影响（g/kW.h）
Variance of CCRES

1号机组
Unit 12号机组
Unit 2

1号机组
Unit 12号机组
Unit 2

高压缸效率 H.P. cylinder efficiency

36.74

58.7

1.36

2.18

中压缸效率 I.P. cylinder efficiency

16.74

43.4

0.62

1.61

低压缸效率 L.P. cylinder efficiency

110.97

77

4.12

2.86

HP-IP漏汽 Gland-Steam Leakage Between H.P.
and I.P. Cylinders

25.18

47.5

0.93

1.76

再减水量 Attemperating water flow of reheater

6.13

22

0.23

0.82

系统泄漏 System leakage

30

40

1.11

1.48

小汽轮机流量 Small turbine steam quantity

40.93

42.25

1.52

1.57

机组真空 Vacuum

33

35

1.22

1.30

5

5

16.11

18.58

负荷率 Load Rate
合

计

Total

C电厂能损分析结构图
Energy loss analysis figure for C power plant影响供电煤耗（g/kW.h）

6

1号机组
2号机组

5
4
3
2
1

空

量

统

机

组

系

小

机

真

减
再

泄

流

漏

量
水

汽
P漏

负

HP
-I

荷

缸
低

率

率
效

缸
中

效
缸
高

效

率

率

0

部分新投产机组主要因素对供电煤耗的影响(g/kW.h)
Main Factors Influence the Coal Consumption Rate of Electricity
Supply (g/kWh)影响因素Influence Factors

A厂

B厂

C厂

#3

#3

#4

#1

#2

负荷率 Load Rate

5

6

6

5

5

缸效率 Cylinder Efficiency

8.3

7.1

10.5

6.1

6.65

HP-IP漏汽 HP-IP gland leakage

0.9

0.8

0.8

0.93

1.76

真空 Vacuum

5

3.67

3.67

1.22

1.3

燃料 Coal

3.68

1.9

1.9
1.52

1.57

小汽轮机流量 Small Turbine Steam Quantity
再减水量 Attemperating water flow of reheater

0.9

0.7

0.7

0.23

0.82

系统泄漏 System Leakage

1.9

1.9

1.9

1.11

1.48

1.5

0.78

2.47

3.14

26.04

29.39

16.11

18.58

补水率 Water Make Up Rate
排烟温度 Exhaust Gas Temperature

0.7

主汽参数 Main Steam Parameter

1.14

加热器、给水温度 Heater and Feed Water Temperature

1.733设备保温 Equipment Insulation
合 计 Total

29.25

部分新投产机组节能降耗潜力(g/kW.h)
Energy-saving potential analysis (g/kWh)
项

目

A厂

B厂

C厂

2006年1～8月运行供电煤耗 Operation CCRES

327.8

324.5

312.9

实际运行供电煤耗较设计值高 Higher than designed

35.6

29

15～20

主要因素影响煤耗总量
Amount caused by main factors

29.29

26～29

16～18.65

6

5

汽轮机通流部分效率、高中压缸之间漏汽、真空、燃料等部分可控因素影响煤耗
Amount caused by part controllable factors

17.88

13.47～16.87

9.77～11.28

主汽参数、系统泄漏、减温水、补水、排烟温度、加热器、保温等可控因素影响煤耗
Amount caused by controllable factors

6.37

6.5

1.3～2.3

可以挖掘的节能潜力
Energy-saving potential

14

12

3～4

负荷率等不可控因素影响煤耗
Amount caused by uncontrollable factors

机组经济性降低的普遍因素
Main Factors Generally Influence the Unit Thermo-Economicsz 汽轮机缸效率低；
Low Cylinder Efficiency
z 凝汽器真空低；
Low Vacuum
z 系统和高压疏水阀门普遍存在内漏；
System Leakagez 煤质变化或者石子煤影响；Poor Quality Coalz 主蒸汽和再热蒸汽参数偏差；
Main Steam and Reheat Steam
Parametersz 锅炉再热器减温水流量大；Attemperating Water Flow ofReheater Highz锅炉排烟温度高；
Exhaust Gas Temperature Highz空气预热器漏风率大；
Air Preheater Leakage Rate Highz机组负荷率低。
Low Load Rate

3. 节能降耗工作重点
Key Work to Improve The Energy-Saving

1、提高汽轮机通流效率
Improve Turbine Flow Path Efficiency
z 调整汽轮机通流部分间隙；
Adjust turbine through flow gap
z 调整轴端汽封间隙；
Adjust seal clearance of axis endz 调整中压缸冷却蒸汽流量；
Adjust cooling steam flow of I.P. cylinderz 调整汽轮机高、中压缸之间漏汽量。
Adjust gland-steam leakage between H.P. and I.P.
cylinders（由于汽缸壁较薄,全实缸状态下会发生变形，因此在调整通流部分间隙时,应按椭圆进行调整；调整前应扣空缸,拧紧密封面螺栓,实测汽缸变形量；调整通流部分间
隙时,应按制造厂提供的间隙
下限执行）

2、改善机组冷端性能
Improve Cold-End System of Steam Power Unitz 真空严密性
Airtight Coefficientz 凝汽器清洁度
Cleanness Factor
z 冷却水流量
Cooling Water Flow Ratez 冷却水温度
Cooling Water Temperaturez 抽空气系统
Air Ejector System

3、治理系统和阀门内漏
Improve Inner Leakage of System and Valvesz加强阀门管理（如建立阀门管理台帐）Strengthen Valve Management
z疏水系统优化（阀门合并、阀门取舍）
Drainage System Optimization

例如：½号高压主汽门前疏水、主汽管道疏水合并；
左、右侧高压导管疏水、高压内缸疏水合并；½号中压主汽门前疏水、热再母管疏水合并；
左、右侧中压导管疏水合并。

日本经验
Japan Experiencez 日方介绍，经过检修消除主机之外的热力系统缺陷后，能回收效率损失部分的60％左右，其中最主要的是阀门泄漏损失；汽机本
体部分，在较好地处理各段密封、间隙和清除通流结垢等问题后可回收其余约40％的损失。
As introduced by Japan engineer, after eliminated the thermal
system (expect turbine)defect, 60% energy loss was recovered.
Valve leakage energy loss is the biggest one. After Adjustment
through flow gap and seal clearance of turbine,40% energy loss
was recovered.

日本经验 • Japan Experience

J-POWER公司介绍的一项检修、改造投资与收效关系的实例值得我们借鉴：曾在一台机组上投资1.3亿日元进行检修和改造，结果
对效率提高的影响仅占约31.5％，而投资0.2亿日元对阀门的处理，解决泄漏问题，对效率提高比例的影响占了57.5％。由于阀门数量
庞大，消缺改造量较繁杂，国内单位一般对检查阀门缺陷以及对消
除缺陷的重视程度不够到位，难以避免修后机组效率达不到预期结果现象。
One Example of unit overhaul introduced by J-Power corporation isinteresting. 1.3 billion yen investment on overhaul and improvement
contribute 31.5% to efficiency improvement. But 0.2 billion yen
investment on valve leakage management contribute 57.5% toefficiency improvement. Because of large number of valves andtedious work, most Chinese power plants didn't pay enoughattention on valve leakage management. That’s why lots of power
plants couldn't reach the goal of overhaul.

4、加强运行调整
Improve Operation Adjustmentz 调整主蒸汽参数
Adjust main steam parameterz 再热蒸汽参数
Adjust reheater steam parameterz 减少锅炉再热器减温水流量
Decrease reheater attemperating water flowz 循环水泵运行方式
Operating mode of circulating water pumpz 煤粉细度Coal finenessz 风量Air rate运行优化措施 • Measures for Optimal Operation
定滑压试验，确定最佳的定滑压控制曲线；Slide Pressure Operation Test
机组微增出力试验和循泵组合运行试验，指导循环水泵的运行方式；
Output Correction for Differing Back Pressure Test and Optimal Operationof Water Circulating Pump Test
机组启停过程中，合理安排重要辅机的启停时间，如，采用汽动给水泵进行启动，减少电泵运行时间等；Optimize Process of Start-Stop for Auxiliary Equipment通过燃烧调整和检修，减少再热减温水流量；
Decrease Reheater Attemperating Water Flow by Combustion Adjustment
采用变频技术，对凝结水泵逐步进行变频改造等；
Application of Frequency Conversion Technology in the Condensation
Pump机组间负荷优化分配方案制定。
Load Optimal Distribution Between Units

5、降低锅炉排烟温度
Decrease Exhaust Gas Temperaturez 漏风（炉膛、制粉系统、空预器入口烟道）
Wind Leakagez 掺冷风量多Cold Blast Ratez 受热面积灰
Ash Fouling of Heating Surfacez 空预器入口风温高
Wind Temperature into Air Preheaterz 一次风率偏高
Primary Wind Ratez 磨煤机出口温度低Temperature of Coal Milling Machine Outlet
z 空预器积灰
Ash Fouling of Air Preheaterz 受热面布置原因
Heating Surface Arrangement

6、减小空气预热器漏风率
Decrease Air Preheater Leakage Ratezzzz

合理的中心密封筒填料密封设计和固定密封装置设计；Reasonable Design of Air Preheater
密封间隙冷态调整质量达到设计要求 ；Seal Gap Cold Adjust Quality Reach the designed Level
顺序控制系统（SCS）不能正常投入运行 ；SCS can't Operate Normally
降低密封压差。
Decrease Seal Pressure Differential个别电厂空预器漏风率高达26%，原因是基
建时空预器转子安装偏斜，密封片与扇形板刮
蹭，主电机电流摆动大，为确保运行现将密封片
与扇形板间隙调整到最大，空预器漏风大。

7、制粉系统优化
Milling System Optimizationz 煤粉细度与燃烧性能、厂用电的关系；
The relation among coal fineness, combustion and power consumption ratez 分离器转速和一次风量的关系；
The relation between rotating speed of separator and primary wind flowz 磨煤机出力分配；
Output distribute of coal milling machinesz 碾磨压力、碾磨面间隙、风环间隙或风量限制块数量调整。
Milling pressure, milling surface gap, air ring gap and adjustment of blast4. 辅机选型与运行情况
Auxiliary Equipment Selection and Operationz 锅炉给水泵扬程较设计工况扬程高10～20％，属于较合理的裕量范围，说明给水泵选型较合理。
Feed water pumps selection is reasonablez 凝结水泵选型裕量偏大；A厂、B厂和C厂与石洞口二厂相比，凝泵扬程高出
12～38m,电机功率大125～325kW。
Condensation pump being on large sidez A厂循环水泵扬程高；与石洞口二厂相比，扬程高出4.9m,循环水泵轴功率增加
260kW，年多耗电超过180万kWh。
Circulation pump lift of A power plant is on large sidez C厂磨煤机容量偏小，在燃用现煤种的条件下，需6台磨煤机才能保证锅炉满负荷运行。Coal milling machine of C power plant is on small sidez A厂送风机、B厂引风机和一次风机耗电率和单耗偏高。
Primary fan and A plant feed fan and B plant draft fan consumption are highz A厂石子煤量大制粉单耗偏大。
Milling system consumption high caused by poor quality coal in A power plant

5. 工程建设启示
Enlightenment From Constructionz 热力系统设计与参数选择
Thermal system design and parameter selectionz 设备选型与匹配Equipment selection and matchingz 产品设计与制造质量
Equipment design and qualityz 安装与调试
Setting and regulationz 其他Others热力系统设计与参数选择
Thermal System Design and Parameter Selection
z
z
z
z
z
z
z

A厂循环水温度设计值偏低。
Circulation water temperature selection was on the low side.
A厂给水泵密封水回水带空气。
Air in water-feeding pump sealed water backwater device.
A厂阀门电动执行机构力矩偏小。
Moment of electric actuator of valves was on the low side.
B厂输煤系统运输能力不足。
Transport capacity of coal system was on the low side.
B厂汽轮机侧放水、放气系统繁杂。
Water drainage system and gas releasing system of turbine are too complex.
B厂凝汽器水室真空泵设计不合理。
Unreasonable design of vacuum pump of the condenser's water chamberB厂未设计胶球清洗装置。
Without rubber ball cleaning device in design热力系统设计与参数选择
Thermal System Design and Parameter Selection
zB厂主汽门和调门卸荷阀内节流孔板结构设计不合理。
Unreasonable design of throttle orifice structure for unloading valve of stop andcontrol valve
zD厂循环水排污水无法回收。
Cycling water sewage reuse can not realize.
zD厂电气系统设计不当，在同类电厂出现的设计错误，在该电厂同样发生。
Unreasonable design of electrify system. Same mistakes happened in otherpower plant.
zD厂输煤系统存在的设计问题较多。
Lots of designed problem exited in coal transport system.

设备选型与匹配
Equipment Selection and Matching
z
z
z
z
z
z
z

A厂输煤皮带秤不准确，低价中标。
Inaccuracy belt-scale of the transport coal system.
B厂凝结水泵扬程偏高。
Lift of condensation pump being on large side.
B厂电动阀门选型与调整不当。
Unreasonable selection of electronic valves
B厂除氧器水位调节阀质量差。
Poor quality of deaerator automatic regulator valvesB厂给水泵冷油器面积小。
Feed water pump oil cooler is on the small sideC厂凝结水泵调节阀调节范围小。
Control valve of condensation pump had limited turning range.
C厂磨煤机出力不足。
Limited output of coal milling machine.

设备选型与匹配
Equipment Selection and MatchingzD厂磨煤机应选MPS中速磨煤机。
MPS medium speed mill are more appropriate for D power plant.
zD厂除灰系统出力不足。
Limited output of ash removal system.
zD厂启动扩容器设计不合理。
Unreasonable design of expander.
zD厂凝结水泵扬程高。
Lift of condensation pump being on large side.
zD厂真空泵选型不当。
Unreasonable selection of vacuum pump.

产品设计与制造质量
Production Design and Produce Quality
z
z
z
z
z
z
z
z

A厂5套油净化装置质量差。
Poor quality of oil purifying device
北京昌宁公司生产的循环水泵质量差。
Poor quality of circulation pump produced by BeiJing ChangNing corporation.
A厂循环水系统阀门腐蚀严重。
Badly corrosion for circulation water system valves.
A厂闭式冷却水阀门门板脱落。
Poor quality of closed circuit cooling system valves.
A厂真空泵噪音大。
High noise of vacuum pump.
A厂静叶可调轴流引风机质量差。
Poor quality of draft fan.
B厂主蒸汽疏水阀产品质量差。
Poor quality of drainage valves for main stop valves.
C厂汽动给水泵前置泵机械密封回水温度超过设计温度。
High temperature of water-feeding pump sealed water backwater.

产品设计与制造质量
Production Design and Produce Quality
zC厂电动给水泵工作油冷却器铜管质量差。
Poor quality of copper tubes of feed water pump oil cooler.
zC厂凝结水泵机械密封质量差、泄漏严重。
Poor quality of mechanical seal for condensation pump. zC厂调节阀质量不佳。
zC厂水环式真空泵间隙偏小，易引起动、静部分磨损。
Movement wearing and small gap of vacuum pump.
zC厂扩容器壳体刚度不足，导致变形。
Limited stiffness of expander.
zC厂汽轮机旁路密封面硬度低，发生内漏。
Leakage of bypass seal surface.
zC厂主汽疏水阀产品质量差，易产生泄漏。
Poor quality of drainage valves for main stop valves.

Poor quality of control valves.
zC厂发电机冷却水管振动。
Vibration of cooling pipe for generator.

安装与调试
Setting and Regulationz A厂轴封蒸汽进、回汽管接反。
Wrong connection of steam pipe for shaft seal.
z A厂7/8号低压加热器防冲刷皮固定方式不妥，导致脱落损伤凝汽器传热管。
Poor setting quality of scour prevention device for low pressure heater.
z A厂5号、6号低加抽汽管接反。
Wrong connection of deflate pipe for low pressure heater.
z A厂凝汽器在线检漏装置调试不合格。
Condenser on-line leak detecting device can not regulate qualified.

其他 • OtherszzzB厂等离子点火装置节油效果显著。
Plasma ignition device brought great economic benefits for B power plant.
B厂空气预热器漏风率小。
Leakage of air pre-heater is small in B power plant.
上海达极胶球清洗装置运行良好。
Rubber ball cleaning devices produced by Shanghai DaJi corporation work well.

6. 日本电力之借鉴
Reference from Japan Experience日本电力水平Status of Japanese Electric Powerz近年来投产的燃煤发电机组均为700~1000MW级超临界或超超临界机组，均配有尾部烟道脱硫、脱硝装置，SOx、NOx排放量均小于50ppm，火电机组的平均效率约为42%，平均供电煤耗约为300g/kW.h。
Units put into production recently are all 700MW~1000MW supercritical or ultra
supercritical units, with desulphurization and SCR system. Emission of SOx and NOx
are lower than 50ppm. Power generation efficiency is about 42% and average coalconsumption rate of electric supply is 300g/kWh or so.
z东北电力公司的原町火电厂装置有两台1000MW机组，1、2号机组分别于1997年和1998年投运，设计发电热效率分别为42.2%和43%；实际运行2号机发电/供电效率达到43.13/40.54%，发、供电煤耗277.04/294.74.
Two 1000MW units of Haranomachi thermal power station belongs to Tohoku
Electric Power Company were put into production in 1997 and 1998. designed power
generation efficiency are 42.2% and 43 ％ ， while operation power generation
efficiency are 43.13% and 40.54%. Coal consumption rate of electric generate and coalconsumption rate of electric supply are 277.04g/kWh and 294.74g/kWh.

日本电力水平Status of Japanese Electric Powerz1983年投产的竹原700MW超临界机组，配有脱硫、脱销装置，年利用率80.3%，
发电效率39%、厂用电率6.8%、供电煤耗306.38g/kW.h。
700MW unit of Takehara thermal power station was put into production in 1983,
with desulphurization and SCR system. Annual utilization ratio is 80.3%, electric
efficiency is 39%, power consumption rate is 6.8% and coal consumption rate of
power supply is 306.38g/kWh.

日 本 电 厂 特 点
Features of Japanese Power Plant
z在日本，核电和煤电是带基本负荷的，大机组、特别是100万级的超超临界机组，负荷率接近100%；
In Japan, nuclear and coal-fired power plants carry primary load. The load ratesof big units especially 1000MW ultra supercritical units are nearly 100%.
z煤质相对稳定。日本燃煤全部依靠进口，来源有澳大利亚、印度尼西亚、中国、
越南等，首先进口的媒质稳定，其次优化配煤工作扎实，他们主要采用分仓上煤。
Coal quality is stable. In Japan, coal depends on import from Australia, Indonesia,
China and Vietnam. Coal quality is stable and coal supply is separated.
z日本火力发电厂重要设备及辅机的制造质量优良、基建周期合理（东北电力的竹原电厂2×1000MW超超临界机组，建设周期是四年半，一般约为四年）；Equipments of Japanese power plants have excellent quality. Capital construction
period is reasonable. (Capital construction period of 2×1000MW ultra supercriticalunits of Takehara thermal power station) is four years and a half. Average period
is about four years. )日本电厂特点
Features of Japanese Power Plantz 设备安装质量良好；发电机组投产后即能长期、稳定在设计性能下高效
运行，基本无非停事件。
Equipments setting have excellent quality. Units can work stably andefficiently after putting into production without unplanned outage.
z 电厂运行维护的关键-精细化管理。特别是对设备检修和运行的精细化管理，使得设备的运行状况较好，一般能达到设计水平，值得借鉴。
The key of power plant maintenance is fine management. Performance ofequipments can reach the designed level by fine management ofequipment maintenance and operation.

我国发电企业普遍存在的问题，在日本并不多见。
Problems generally exit in Chinese power plants rarely happen
in Japanese counterparts.
z例如我国机组运行效率低、真空低、阀门内漏、锅炉排烟温度高、锅炉爆管、投产后大量进行技术改造项目等，在日本基本不存在，他们的机组投入商业运行后一直
基本保持设计效率，各项技术指标也满足设计要求。他们认为，如果为了提高机组
的性能，才采取技术改造的方式。所以，我们想从电厂直接得到我们所需的东西比较困难，但是可以间接的得到启发。
Such as load rate low, vacuum low, leakage of valves, exhaust gas temperature high,boiler pipe explosion and lots of technical reforms and so on. In Japan, units keep
designed efficiency after put into production. They believe that technical reform is toimprove units performance not for achieve designed performance. We can learnsomething from this point.

借鉴之处 • Reference Points
我们电力行业能够做到的、也应该为之努力的目标：The goals Chinese power industry should and could working on:z积极推行负荷优化调度；国家电网公司应根据发电设备的能耗水平进行负荷调
度，可分等级区别对待，从政策方面向节能降耗倾斜，鼓励大容量、高参数的高效、低耗机组和电厂。
Optimal Load Dispatching . State Grid should dispatch load based on thermoeconomics to encourage high efficiency units.
z系统设计； 电厂设计应进行优化，分析其热力系统布置、阀门设置、锅炉受热
面等的合理性。避免或者减少日后的技术改造。
Optimal thermal system design. Power plants design should be optimized to avoid
technical reform later, such as thermal system, drainage valves and boil heatsurface and so on.
z设备选型； 一是产品适应性、三是裕量合理性、二是质量保证性。
Equipment selection. Adaptability, reasonable allowance and excellent quality.

借鉴之处 • Reference Pointsz建设周期； 确定合理的建设周期，保证制造、安装、分部试运、试验项目、缺陷
消除等都能全部达到技术要求，减少投产后的不安全、不经济因素。
Capital construction period is reasonable. Make sure that equipment production,
setting, regulation, test and defect elimination all reach the designed require. Cut
down insecurity and uneconomic factors.
z安装质量； 在此强调汽轮机通流间隙的调整，一定要按技术要求控制在合理的范围之内，切忌为了便于启动而人为放大。
Setting quality. Turbine through flow gap adjustment should based on technicalrequiring exactly. Do not amplify the gap for the convenience of turbine start-up.
z运行维护； 日本及德国企业的管理核心就是-精细化管理，运行人员时刻按照机组
运行变化的要求在调整参数和设备，确保机组在最佳性能下工作；每一个维修人员均保证自己所负责的工作满足技术要求。
Operation maintenance. Fine management is the core of Japanese and Germany
corporation management. Operation staffs adjust the parameters timely to make surethat units are under excellent performance. Very staff should fulfill the technicalrequire of the duty.

7. 几点建议
Several Suggestionsz 初设阶段对机组热力系统与主要辅机设计优化、
核算
Optimize the thermal system and auxiliary
equipments during prelhoinary design stage.
z 新投产超临界600MW机组综合性后评价
Post-evaluation of new supercritical 600MW
units.
经济性、安全性、可靠性、可维修性、可操作性.
Economy, security, reliability, maintainability andoperability.

z超临界600MW机组主要设备和系统配套设计评估研究
Study on assessment for main equipment and system matching of supercritical 600MW
units.
锅炉设计与燃烧特性适宜性校核；Checking for boiler design and combustion
制粉系统及设备适宜性评价；Evaluation for coal milling system and equipments
三大风机适宜性评价；Evaluation for three main fans凝结水泵、循环水泵、给水泵适宜性评价。Evaluation for three main pumpsz超临界600MW机组达到设计性能的技术条件研究
Study on technical requests to match the designed performance for supercritical 600MW
units.
设备维护的技术要求；Technical requests of equipments maintenance运行监督的技术要求；Technical requests of operation supervision优化调整的技术要求；Technical requests of optimal adjustment
技术改造的途径。 The approach of technical reformz以西安热工研究院为平台建立发电技术协作网，数据交换，信息互通，技术共享。
Setting up power technical cooperation net based on TPRI to realize data switching ,information exchanging and technology sharing.

谢 谢！
Thank you!

Day 2 Tuesday 16 October 2007
Session 7: Energy and Water Saving in Coal-fired Power Plant

Speech 4 Japan
Renovation of Coal-fired Power Plants

Dr. Tohmei Takekawa
General Manager
Business Promotion Department
Japan Coal Energy Center (JCOAL)
Co-author
Mr. Li YuSheng
Mr. Hao JiHong
China Electricity Council
PR ChinaTohmei Takekawa
１. Academic Record:
1975

Faculty of Engineering, Hokkaido University, Japan (Bachelor of Applied Chemistry)

1976

Faculty of Engineering, Hokkaido University, Japan (Master of Applied Chemistry)

1988

School of Chemistry, University of Newcastle upon Tyne, UK (Ph.D.)

２. Job Record:
1975

Joined Coal & Coke Research Laboratory, Technical Research Center, NKK Corporation

1986

Senior Researcher, Carbon Materials Reserach Laboratory, Technical Research Center

1989

Senior Researcher, Chemicals Research Department, Technical Research Center

1992

Senior Engineer, New Business Development Division

1995

Joined Clean Coal Technology Center,

New Energy and Industrial Technology Development Organization (NEDO)
1997

Director, Key Technology Research and Development Division,

Industrial Technology Research and Development Department
2000

Director, International Affair Division, General Affair Department

2001

Director, Global Environment Technology Department

2002

Chief Representative, NEDO Jakarta and Sydney Offices

2004

Director General, International Cooperation Department

2005

Joined JCOAL, Head of Business Promotion Department

Renovation of coal-fired power
plants in China- Bilateral model project for energy conservation andenvironmental protection -Tohmei Takekawa*, Li YuSheng**, Hao Ji Hong***Japan Coal Energy Center (JCOAL)**China Electricity Council (CEC)in cooperation with Japan Bank for International Cooperation (JBIC)
16 October 2007
The 2007 APEC Clean Fossil Energy Technical and Policy Seminarin Xi’anContents
1. Background
2. Objectives
3. Examples of related technologicalbackground
4. MOU and Conference Book signed by
JBIC, CEC and JCOAL
5. Progress and business base cooperation

1. Background• More than 50% of coal is consumed in power plants in
China. Accordingly, efficient and environmentally friendly
use of coal in power plants is expected to contribute tosaving of coal resource and local / global environmental
issues.
• Japanese power and engineering/manufacturing
companies have experienced to maintain aged plants
without decreasing efficiency and sometimes withincreasing efficiency under strengthened environmental
measures beyond designed base. (Ex. 40% of gross thermal
efficiency has been maintained with 40 years old plant)• Bilateral business cooperation for power sector has been
investigated among energy audits companies, powercompanies and engineering companies in Japan andChi

2. Objectives
zTo promote improvement of efficiency andenvironmental measures for existing
medium size coal-fired power plants in
China through establishing technologicaland financial cooperative scheme.
zTo promote mutual business basecooperation in power sector.

Contents
1. Background
2. Objectives
3. Examples of related technologicalbackground
4. MOU and Conference Book signed by JBIC,
CEC and JCOAL
5. Progress and business base cooperation

3.1 Change in the concentration ofpollutants in Japan (1970-2001)

SPM: 1,541 APMSs ave. 0.030 mg/m3 .
SOx: 1,489 APMSs ave. 0.005 ppm
NOx: 1,465 APMSs ave. 0.016 ppm

SPM

APMS : Air Pollution Monitoring Station
RAPMS: Road side Air Pollution
Monitoring Station

SOx

NOx

3.2 SOx and NOx emissions per unit electricity
generated by thermal power industryg/kWh3.3 Near zero emissions from coal-fired
power plants in Japan
Tachibanawan (J-power)

Commenced in 2000.
Power output: 1050MW x 2
USC: 25MPa 600/610C
Net Efficiency: 41.5%(HHV)
SOx: 50ppm(Wet type De Sox)
NOx: 45ppm（SCR)
SPM: 10mg/m3N（ESP)
No1 unit of J-power Isogo coalfiring power plantCommenced in 2002 (Former No1)
Power output：600MW
USC: 25/4.41MPa, 600/610℃
SOｘ： 20ppm（Dry type De-SOx) (60)NOｘ： 20ppm（Dry type De-Nox SCR)(159)
SPM： 10mg/Nm3(ESP) (50)

3.4 Age of existing coal-fired power plants
140,000

132,862

112,795

120,000

Cumulative Capacity （MW）

105,780
100,000
82,55480,000

China
India
USA
Japan

77,28760,00040,00026,631
25,24519,922
17,01520,000
2,329
1,852

6,776
5,956

17,126

14,87910,324

1,093

2,804

4,285

41Years and Older(1965)

31-40 Years Old(1966-1975)

21-30 Years Old(1976-1985)

4,937

0
11-20 Years Old(1986-1995)

0-10 Years Old (19962005)

Sources: Pradeep J. Tharakan, USAID-ECO-Asia Clean Development and Climate Program,
ASEAN Energy Business Forum (AEBF) 22nd -24th Aug.,2007 and Coal Note 2005/2006

3.5 Comparison of gross thermal
efficiency of coal-fired power plant
Gross thermal Efficiency(%)

Japan

N Europe
UK/
Ireland

Korea

Germany

Australia

USA

FranceN Europe

France

China

India
Japan

UK/Ireland
USA
Australia

Germany

China

India
Korea

＊Thermal Efficiency: Gross thermal efficiency (LHV base）
Source：UPDATED COMPARISON OF POWER EFFICIENCY ON GRID LEVEL（2006年）（ECOFYS Co.）11

3.6 Experience of a Japanese company inChinaKyushu Electric Power Company
Shandong Province Huangtai No7 300MW Unit
Equipments

Manufacturer

Specification

BoilerMitsubishi

Max. 1,025t/h

TurbineDongfang

535/535 16MPa

EP

Mitsubishi

Efficiency 99.3%

Result of Rehabilitation
Designbase

BeforeAfter

Boilerefficiency (%)

89.94

88.66

89.36

+0.70

Turbineefficiency (%)

42.98

39.64

43.27

+3.63

Total efficiency
(%)

37.66

33.17

37.57

+4.40

Coal comsump(kT/y)

752

664

-

CO2 emission(kT-CO2/y)

1,809

1,597

- 212

88

3.7 Various kinds of losses affect on
turbine efficiency
z Turbine Internal Losses• Profile Loss
• Secondary Loss
• Tip Leak Loss
• Labyrinth Loss
• Exhaust Lossz Valve Throttling Losses
z Mechanical Losses
z Generator Lossz Pressure Drop Losses of Pipingz Various Steam Leak Losses
z Various Losses due to Deterioration

3.8 Renovation of existing coal-fired power plant
Ex1. Retrofitting by Hitachi for
Liddell PS turbines in Australia

500MW

Renovation(1) Original LP turbine (GEC)

Ex2. Advanced last stage blades by
Toshiba in Rumania and Bulgaria〇improved section

520MW(2) After retrofitting by Hitachi

4. MOU and Conference Book signingceremonies by JBIC, CEC and JCOAL

MOU signing ceremony(April 12, 2007)

Conference book signingceremony (Sep. 27, 2007)

Both were signed with attendance of Mr. Akira Amari,Minister of Economy, Trade and Industry (METI), and Mr.
Ma Kai, Chairman of National Development and Reform
Commission (NDRC)
15

Contents
1. Background
2. Objectives
3. Examples of related technologicalbackground
4. MOU and Conference Book signed by JBIC,
CEC and JCOAL
5. Progress and business base cooperation

5.1 Progress until now
1) April 12, 2007; MOU was concluded by three parties.
●JBIC; Making of renovation business applicable to CDM and investigation of financial support scheme.
●JCOAL, CEC; Investigation of cooperation scheme for energy and environmental audits.

2) May, 2007; Trial energy audits by Japanese and Chinese companies for Yingkou
Power Plant (Liaoning), to investigate cooperation methods.
●Obtaining and evaluation of performance test and audit report made by Chinese companies.
●Site survey by Japanese and Chinese companies.

3) June, 2007; Inspection of Japanese coal-fired power plants by CEC, TPRI andChinese power companies.
●Expectation for not only hardware technologies, but also cooperation of software technologies,
such as operation and maintenance of the equipment.

4) June to August, 2007; Meeting by three parties (JBIC, JCOAL, CEC).
●Making of report on trial energy audits results conducted by Japanese companies and agreement about basic thinking
of energy audits cooperation.
●Proposal and consultation about business and financing cooperation scheme (Tokyo, Beijing).
●Forming of implementation procedure examination committee and investigation of cooperation
methods among Japanese and Chinese diagnosis related companies.

5) September 27, 2007; Conference Book was signed by three parties●Mutual introduction of candidate companies including energy audits companies, power companies, engineering
companies.
●Establishment of joint committee for further technological assessment and investigation of cooperation sheme.

175.2 JBIC Proposed financial support forrenovation of Coal Fired Power Station in China
Cooperation
FieldsChina Electricity
Council① Technology

JBIC

② CDM
③ Financing

AdviceFinancing

Energy Suppliers Coal

AdvicePower Station
Distributors

J-COAL

Payment
Technology/Equipment/Parts
SupplyElectricity

Japanese
Technology
Suppliers

Payment
Carbon Credits

Energy Saving
CO2 Emission Reduction
Rehabilitation by new turbine at 300MW⇒ Saving of 200,000 CO2e ton saving

Carbon Credits
BuyersArrange18

5.3 CDM: Report of twenty-ninth meeting of themethodologies panel (24-28 Sep. 2007)

5.4 Procedures and possibilities of mutual cooperation
Power plant/Group company

Possibility of cooperation between Japanese and Chinesecompanies

Engineering,(Order placing/applying source) Energy audits, Procurement,
Constructio
andESCO, andn company
consultant
CDM
developer
Share level

Basic analysis

Japan

China

○

◎

Japan

China

Japan

China

investors,
financers,
CER
acquisition

Japan andChina jointcommittee,
JBIC,
JCOAL,
CEC

Japan

Japan

China

◎

◎

◎

◎

China

Technical
evaluation
Detailed analysis, improvement
plan, estimate, preparations for

○

○

◎

◎

○

○

application of CDM
Validity evaluation for
financingConstruction work

Improvement of intensity anddelivery of CER

△

◎

◎

◎

◎

○

◎ 20 ◎

5.5 Work schedule
Year
Item

Month

Preparation andadjustment

Trial diagnosis

Pre-business
phase

Business phase

2007
April – June

July – Sep.

2008
Oct. – Dec.

Selection of power plants for trial diagnosis

Jan. – March

April –

・

Adjustment and listing up of target power plants
Packaging of business and financing
Implementation of trial
diagnosis (1 plant)

Implementation of pre-business diagnosis(Multiple business models are targeted.)

Implementationof business21

Day 2 Tuesday 16 October 2007
Session 7: Energy and Water Saving in Coal-fired Power Plant

Speech 5 PR China
Status of Water Saving and Key Analysis in Chinese Coal-fired
Power Plants

Mr. Yang Baohong
Director
Water Treatment Technology Department
Thermal Power Research Institute (TPRI)PR China

TPRI

中国火电厂节水现状及技术关键分析
Statues and Technical Key Analysis on Water Saving
in Chinese Power Plants杨宝红
Presented by: Yang Baohong

西安热工研究院有限公司
Thermal Power Research InstituteOct. 16, 2007
Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

TPRI
内

容

Content—

中国火电厂用水现状
Statues of Water Saving in Chinese Power Plants—节水关键技术环节分析
Technical Key Analysis on power plants water saving—

几个误区
Several Misunderstands

Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

TPRI
单位发电量取水量(2006)

Water Intake,kg/kWh

Water Intake in 2006

5.00
4.00
3.00
2.00
1.00
0.00
0

5

10

15

20

Pow er Plants No.

Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

TPRI
60

U: 地下水; S: 地表水；R：再生水 M: 矿井水

50

水源类型
Water Source

百分比,%

50
40
30

21.5
14.3

20
10

7.1

7.1

M/U

R/U

0
U

S

U/S

问题：井水流量逐年降低，供水能力下降。
― XD电厂的地下水位由原来的40m~50m曾经降至80m；后通过回灌才使
地下水位有所回升；― YS电厂：1994年至2001年，已有7眼井枯竭；最大连续供水能力由1994
年的0.3m3/s下降至0.2m3/s，降低了33%。
Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

TPRI
节水关键技术环节
Key step for water saving work in power plants

技 TechnicalRequest术 and Cost
难
度
及
成
本

零排放
Zero
Discharge

废水综合利用W.W reuse

提高浓缩倍率Enhancing K

干除灰
Dry ash removal

节水量 Water savings
Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

TPRI
ConcentrationRatio
Ratio~~Water
WaterIntake
IntakeConcentration

Water con. kg/kWh

5
4
3
2
1
0
1

2

3

4

5

6

7

8

K

Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

TPRI
影响浓缩倍率的主要因素Factors affecting tower concentration ratio— 防垢；补充水的水质与处理方式
Anti-Scale; Quality and treatment process of tower makeup— 防腐蚀；凝汽器管材质；Anti-corrosion; Materials of Condenser tube
— 防细菌、藻类滋生；
防细菌、藻类滋生
Anti bacteria & alga Growth— 浓缩倍率的稳定控制
Reducing the fluctuation of Concentration Ratio

Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

01
.0
1
15 .20.0 06
1
29 .20.0 06
1
12 .20.0 06
2
26 .20.0 06
2
12 .20.0 06
3
26 .20.0 06
3
09 .20.0 06
4
23 .20.0 06
4
07 .20.0 06
5
21 .20.0 06
504 .20.0 06
6
18 .20.0 06
602 .20.0 06
7
16 .20.0 06
730 .20.0 06
7
13 .20.0 06
827 .20.0 06
810 .20.0 06
924 .20.0 06
908 .20.1 06
022 .20.1 06
005 .20.1 06
1
19 .20.1 06
1
03 .20.1 06
2
17 .20.1 06
2
31 .20
.1 06
2.
20
06

TPRI
Actual fluctuation of Tower concentration ratio in Power plants DZ

5
#11
Block
Block
#22
Block
#33
Bkock
#4 4

浓缩

倍率

4,5

4

3,5

3

2,5

2

1,5

1

0,5

0

Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

TPRI

2. 采用干除灰 Adopting Dry Ash Removal System1) 为什么采用干除灰? Why adopting dry ash remove system?
为了满足冲灰的需要，人为降低循环水浓缩倍率;
To meet the demand for ash flushing, tower concentration ratio may be kept inlower level frequently2) 现状 Present Situation— 原设计采用干除灰的电厂仅占35.7%；
Only 35.7% of power plants adopted dry ash removal system originally— 很多电厂增加了干灰分选设备，没有干灰储存设施或场地，外销成为干灰的唯一出路。大部分电厂的水力除灰系统依然保留。水力除灰需水量大。
Many power plants added cyclone separation devices for dry ash sale in thepast ten years, but no dry ash store vessel. Therefore, two systems for ash
removal, both dry and wet, existing in many power plants..

3) 达不到设计的灰水比：
The ash concentration is usually lower than the designed value, because of:— 灰浆在管道内沉积 Ash settled inside slurry transmitting pipe;— 管道结冰 Slurry frozen inside pipe during winter;
Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

TPRI
3. 废水综合利用 Wastewater Reuse顺序 Sequence— 避免废水产生; Avoiding wastewater generation— 减少废水数量; Reducing wastewater flow— 废水综合利用；Reuse wastewater

要点 Key Point
废水综合利用方案的制定要在全厂水平衡优化的框架内进行；
Water balance optimizing is the basis of Wastewater reuse

Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

TPRI

废水回用方法Typical wastewater reuse procedures

Fresh water新鲜水

上朔式（需要处理，成本较高）
Reuse in up orderService waterneed treated, expensive
工业冷却水Reuse in down order
下串式

循环冷却塔
Cooling Tower（不需要处理，成本低）循环回用Reuse inRecir.

Coal Yard …
煤场、栈桥
处理装置
Treatment Device

Slag & Ash Removal
FGD、除渣、除灰

Slag Removal Device渣系统处理装置Treatment Device

Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

TPRI
常见的问题 Common Problems ：— 对废水的综合利用没有规划；尤其是多期扩建的机组。
Wastewater reuse is not planed for overall plant, especially for those
constructed by several phases
废水回用的成本高、工艺复杂、投资高；Expensive, Complex, High invest— 对水平衡试验的重要性认识不足；Lack of water balance test
— 没有分类回收、分类处理的设施；Wastewater is not collected andtreated in sorts
废水处理设施按照达标排放的要求设计的，其处理效果满足不了废水回用的要求。Most of wastewater treatment units are designed for discharge—高含盐量废水的回用成本高High cost for high TDS wastewater reused
Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

TPRI
高含盐量废水的消耗
High TDS WW could be consumed for:

高含
高含
盐量
盐量
废水
废水
High TDS W.W

除灰
除灰

For Ash Removal

除渣除渣

For Slag Removal

FGD
FGD

For FGD

Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

TPRI

3. 几个误区 Misunderstandings

1. 零排放 Zero Discharge-

零排放：环保的要求；Environmental protection-

代价太大; Too high cost

2. 循环冷却与直流冷却 Circulation Cooling and Once-through Cooling-

循环冷却没有热污染，但有化学品污染；For Circulation Cooling : Chemical pollution-

直流冷却有热污染，但没有化学污染；
For Once-through Cooling : Heat Pollution
地表水源充足的地区应该坚持直流冷却；If the surface water source isplentiful, once-through cooling is better.

3. 空冷电厂采用中水回用 Municipal wastewater use
对于空冷电厂，就需要进行认真分析。
例如，华能铜川电厂二期水的需求量较小，但中水输送距离很长，达到30km以上，
建设费用较大。 For Dry cooling, a few water demanded, the expensive
municipal wastewater use system may be not suitable.
Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

TPRI

Thank you !

Yang Baohong/TPRI Oct.16, 2007 APEC Clean Fossil Energy Seminar, Xi’an, 2007

Day 2 Tuesday 16 October 2007
Session 7: Energy and Water Saving in Coal-fired Power Plant

Speech 6 PR China
Control of PM from coal combustion

Dr. Qiang Yao, Professor
Head
Department of Thermal Engineering
Tsinghua University
Director
National Engineering Research Center of Industrial Boiler and Clean Combustion
Technology of Domestic Coal
PR China

姚 强
清华大学教授 ，博士。曾任浙江大学能源工程学系教授、博士生导师， 热能工程研究所副所长，国家水煤浆工程研究中心浙江大学燃烧技术研究所副所长，国家教委洁净燃烧开放实验室副主任。
现任国家教育部长江学者首批特聘教授，清华大学热能工程研究所
所长，煤清洁燃烧国家工程研究中心主任、《工程热物理学报》和《洁净煤技术》的编委，国家”十五”863洁净煤主题专家组成员。

APEC“清洁化石能源技术研讨会”煤燃烧产生的颗粒物控制
Control of PM from coal combustion

中国环境科学研究院

姚强，Yao Qiang
清华大学，Tsinghua University
APEC“清洁化石能源技术研讨会”

Contents(内容）New developments in the PM formationin the urban area（城市PM形成的新机制）
Coal combustion and PM formationfrom Power plant（煤燃烧与颗粒物形成）
Mercury pollution from Power plant（电厂汞污染形成）
Research on control methods of PM（PM控制方法研究）
Conclusions（结论）3APEC“清洁化石能源技术研讨会”燃烧源可吸入颗粒物(PM from Power plant)源于燃烧过程产生的颗粒物
由燃烧源直接排放产生的一次颗粒物(primary PM)
燃烧源排放的一次气态前体物（如SO2,
NOx和VOCs）在大气中转化生成的产物
即二次颗粒物(Secondary PM)。
燃烧源可吸入颗粒物化学成分(chemicalcompositions)有机颗粒物、烟炱
硫酸盐、硝酸盐、铵盐、水溶性有机物

4APEC“清洁化石能源技术研讨会”

北京高污染2005年1月23日(high pollution day: Jan.23,2005,Beijing)
4

Particle diameter [nm]

10

3

10

-3

dN/ dlog Dp [cm ]4> 7.7*100< 5.2*10

2

10

1

10

4

8

12

16

20

24

8

6

6
4
4
2

NumberVolume

0
0

4

8

12

16

20

2

Volume concentration
23-3[*10 μm cm ]Number concentration
4-3[*10 cm ]0024Hour of day

5

APEC“清洁化石能源技术研讨会”

颗粒物数谱分布特征(PM size distribution)

6

APEC“清洁化石能源技术研讨会”

颗粒物数谱分布特征新粒子生成(New PM3－10nm)
July. 03

4

600
400

10

3

10

2

10

1

200

-3

100
80
60
40

0.0
2.5e+45.0e+47.5e+44> 7.7*100< 5.2*10

20

4

8

12

16

20

246

0

NumberVolume 3nm - 1 μm
Volume 1 μm - 10 μm

10
8

4

6
4

2

2
0
0

4

8

12

16

20

10
8
6
4

Volume concentration
23-3[*10 μm cm ]0

Number concentration
4-3[*10 cm ]dN /dlog D p (cm -3 )dN/ dlog D p [cm ]diameter nm

Particle diameter [nm]

10

4

8

12

16

20

24

T im e of d ay

024

Hour of day观测期间新粒子生成频率 2004年3月-2005年2月
80
70

Percentage

60
50
40
30
20
10
0
M ar. Apr. M ay. Jun.

7

Jul. Aug. Sep. Oct. Nov. Dec. Jan. Feb.
2004 & 2005

APEC“清洁化石能源技术研讨会”

Contents(内容）New developments in the PM formationin the urban area（城市PM形成的新机制）
Coal combustion and PM formationfrom Power plant（煤燃烧与颗粒物形成）
Mercury pollution from Power plant（电厂汞污染形成）
Research on control methods of PM（PM控制方法研究）
Conclusions（结论）8APEC“清洁化石能源技术研讨会”实验采样系统(Sampling system)

EPA Method 17

Andersen Stack Impactor

Sampling instrument: Andersen 8-stage Stack Impactor (stack temperature)Sampling method: U.S. EPA Method 17
All of fly-ash particles were sampled with aerodynamic diameter classification.
9
可吸入颗粒物之间协同脱除效应与抑制机理 2002CB211606
APEC“清洁化石能源技术研讨会”实验现场(sites and Stack Impactor)

The Impactor with fly-ash particularmatter after sampling

10

APEC“清洁化石能源技术研讨会”

Morphological: SEM images of supermicronparticles from PC plants——— Stage 5
1.65~3.29μm

The shape of supermicronparticulate is quite spherical.

To imply two aspects:——— Stage 6•

The shape of burn-out ash isnearly originally spherical.

•

Coagulation/agglomerationof submicron particle forms
larger spherical supermicronparticles;

1.05~1.65μm,

11APEC“清洁化石能源技术研讨会”

SEM images of submicron particles(PM1) from PC——— Stage 7

The shape of submicronparticles is also quite spherical.

0.71~1.05μm——— Stage 8<0.71μm,

The formation of regular sphericalshape of submicron particles (PM1)can be explained by a mechanism of
evaporation-nucleation –condensation–
coagulation

12
可吸入颗粒物之间协同脱除效应与抑制机理 2002CB211606
APEC“清洁化石能源技术研讨会”

Morphological: SEM images of supermicronparticles from CFB plants——— Stage 4
3.29~5.08μm
The shape of supermicronparticulate is irregular, nonspherical.

——— Stage 5
1.65~3.29μm

The agglomerates ofspherical, flake-like,floccus-like, …ofparticles

13
可吸入颗粒物之间协同脱除效应与抑制机理 2002CB211606
APEC“清洁化石能源技术研讨会”

SEM images of submicron particles (PM1) from
CFB——— Stage 7
0.71~1.05μm

The mechanism of evaporationnucleation –condensation for
PC can’t well explain theformation of submicron particles(PM1) in CFB.

——— Stage 8
Then, what is mechanism?
<0.71μm,

Next page!

14
可吸入颗粒物之间协同脱除效应与抑制机理 2002CB211606
APEC“清洁化石能源技术研讨会”

燃煤炉的对比－PM10、PM1的浓度

6000

5521

质量浓度 (mg/Nm3)

5000
4000

4000

3547

煤粉炉1
煤粉炉2
水煤浆炉
煤CFB炉

3169
3000
2224
2000

1851
1426
1076

1000
83 63 20 92

0
PM17

PM10
颗粒物

PM1

15

APEC“清洁化石能源技术研讨会”

Different size distribution－质量分数的粒径频度分布(%)

size distribution
45%
40%
35%
30%
25%
20%
15%
10%
5%
0%
0.1

1

10

100

Dp
煤粉炉1

水煤浆炉

煤链条炉

煤粉炉2

煤CFB炉

16
可吸入颗粒物之间协同脱除效应与抑制机理 2002CB211606
APEC“清洁化石能源技术研讨会”

Mass concentrations and enrichment of traceelements of PM from CFB plantsemi-volatile metals
400

350

weak enrichment

200

Co2286

250

ppm

250

300

150

Sn1899

No obvious
enrichment

As1890Zn2062
Pb2203

Ni2316
Cu3247
Cd2265

200
150

100

100
50

50
0
0

1

2

3

4

5

6

7

8

9

0

10

0

Stage

1

2

3

4

5

6

7

8

9

10

Stage

5

RET
4
As 18 90
Zn20 62

3

RET

ppm

300

Cr2835350

Pb22 03Co 22 86

2

1

0
0

1

2

3

The RETij value of high semi-volatile As atlast stage is 3~4, which is one-tenth ofthat from PC ;medium semi-volatile metals such as Zn
and Pb, the RETij are about 2 and 4; thatis 1/4 of PC results

17
可吸入颗粒物之间协同脱除效应与抑制机理2002CB211606
4
5
6
7
8
9
10
Stage
APEC“清洁化石能源技术研讨会”

主要内容

2.3 燃烧过程中颗粒物的形成和控制

荷电颗粒过滤特性的研究

18

APEC“清洁化石能源技术研讨会”

2.3 燃烧过程中颗粒物的形成和控制

燃烧条件对颗粒物形成的影响
Air

1250

Flow meter pump

Coal feeder

1200

Auto valve

1150

Metal solution

Flowmeter

1100

Temper at ur e/ ℃

1050
BurnerCompressor

1000

autovalve

Flowmeter

Eletric heater

950

T1

P1

900
850
800

T2
T3

Controlsysytem
I/O

T4
T5

750
700
Liquid Natural Gas

650
0

500

1000

1500

2000

2500

P2

T8

P3

T9
T10

Primary Air Fan

T11

Cooling tower

P2

Secondary Air Fan

3000

Hei ght ( Fr om t he out por t of bur ner ) / mm

P1

T6
T7

T12

P4

Resident time:

P4

T13
T14

P7

P6

0.15 s

0.4 s

P8

P9

ID Fan

T15

0.8 s

P5

P10

Bag Filter

P5 P10

最终排放口(受热面冷却)P10：190 ℃

Pump

1st Heatexchanger

2st Heatexchanger

19

APEC“清洁化石能源技术研讨会”

2.3 燃烧过程中颗粒物的形成和控制

燃烧条件对颗粒物形成的影响

Cooling

SecondDilution

SampleFirst Dilution• Two stages of dilution• Highest temperature(1500 K )• Accurate diluted ratio control• 13 stages (30nm-10μm) of ELPI20APEC“清洁化石能源技术研讨会”

2.3 燃烧过程中颗粒物的形成和控制

燃烧条件对颗粒物形成的影响

高温稀释比对取样结果的影响
160

6

1.00E+008

x 10
4

140

80

3

6.00E+007

4.00E+007

60

3

40

dN/dlogD/cm-3

3100

8.00E+007

dN/dlogDp (1/Ncm )dM/dlogDp (mg/Nm )

120

20, 3
24, 3
49, 6
73, 8
146, 16

3.5

Mass Con.
dM18
dM75
Num. Con.
dN18
dN75

2.5
2
1.5
1

2.00E+007
0.5

20

0

0
0

110

220

330

440

550

660

770

880

990

0.00E+000
1100

0.1

0.2

0.3

0.4

0.5
0.6
Dp/μm

0.7

0.8

0.9

1

Aerodynamic Equivalent Diameter, Dp (nm)P2：920 ℃

P4：800 ℃

21

APEC“清洁化石能源技术研讨会”

2.3 燃烧过程中颗粒物的形成和控制

燃烧条件对颗粒物形成的影响

(K)

(S)

60

2.50

54

DR18
DR70

2.25

48

2.00

42

wt % of S in PM1

1.50
1.25
1.00
0.75
0.50

36
30

DR18
DR70

24
18
12

0.25

6
0.00
10

100

1000

0
10

Aerodynamic equivalent diameter, Dp/nm

100

1000

Aerodynamic equivalent diameter, Dp/nm(Na)

1.00E+008

20

DR18
DR70

16
14

dN/dlogDp (1/Ncm3)

8.00E+007

18

12

4.5

4.00E+007

4.0

2.00E+007

3.5

0.00E+000

0

10

(Ca)

5.0

Diluted Ratio
18.6
74.6

6.00E+007

110

220

330

440

550

660

770

880

Aerodynamic Equivalent Diameter, Dp (nm)

8
6
4
2

990

1100

wt % of Ca in PM1

wt % of Na in PM1

wt % of K in PM1

1.75

DR18
DR70

3.0
2.5
2.0
1.5
1.0

0
10

100

Aerodynamic equivalent diameter, Dp/nm

1000

0.5
0.0
10

100

1000

Aerodynamic equivalent diameter, Dp/nm

稀释比的影响主要通过硫与碱土金属作用来体现
22

APEC“清洁化石能源技术研讨会”

2.3 燃烧过程中颗粒物的形成和控制

燃烧条件对颗粒物形成的影响
Temperature gradient,
Metallic species,
Oxygenic conditions

Complex behaviors:
Soot formation
Carbonization
Oxidation

Concentric
onion-like
Capsule-like
Graphenefibre

火焰区域soot及无机物质的行为23

APEC“清洁化石能源技术研讨会”

2.3 燃烧过程中颗粒物的形成和控制(a)燃烧条件对颗粒物形成的影响

(b)Graphene layer

core
shell
Burn out and emitting

(c)

(d)

•Fringe•Fringe length•Fringe separation•Tortuosity

Reactivity
Carbonization
Nanostructure of soot24

APEC“清洁化石能源技术研讨会”

2.3 燃烧过程中颗粒物的形成和控制

排放：Soot & 单晶Cr (1)燃烧条件对颗粒物形成的影响

Soot & 单晶Cr (2)25

APEC“清洁化石能源技术研讨会”

Contents(内容）New developments in the PM formationin the urban area（城市PM形成的新机制）
Coal combustion and PM formationfrom Power plant（煤燃烧与颗粒物形成）
Mercury pollution from Power plant（电厂汞污染形成）
Research on control methods of PM（PM控制方法研究）
Conclusions（结论）26

APEC“清洁化石能源技术研讨会”

Scheme of the site experiment27

APEC“清洁化石能源技术研讨会”实验电厂·地理位置

28

APEC“清洁化石能源技术研讨会”

六家电站汞平衡(Hg balance in Powerplant)
90

90

电厂 3

煤中汞
0
Hg (g)

600 MW
PC, ESP

80

40
30

电厂 1

电厂 2

20

220 MW
PC, ESP

600 MW
PC, ESP,FGD

80
除 尘 器脱除灰中汞

70
60

电厂 5
电厂 4

200 MW
PC, FF

50 MW
PC, FF

50

电厂 6

40

135 MW
CFB, ESP

30
20

出
口
锅
炉
入
口
ES
P
入
口

FF

出
口
锅
炉
入
口
FF
入
口

FF

SP

D
FG

SP

口

P
ES

入

入
P
ES

锅
炉

出
口
锅
炉
入
口
FF
入
口

0
ESP 出口

出
口
锅
炉
入
口
ES
P
入
口
E

0

出
口

10

出
口
锅
炉
入
口
ES
P
入
口
E

10

口

单位时间汞质量 (g/h)1) 汞平衡达到79.2%~138.6%
2) 电厂汞排放强度决定于三个因素；3) 汞排放形态差别很大。

50

Hg (g)Hgp

惯 性分离器粗灰中汞
底渣中汞
脱硫石膏中汞

70
60

2+

29

APEC“清洁化石能源技术研讨会”

气态汞的氧化( Gas Hg oxydation)
90

90

电厂 3
600 MW
PC, ESP80

煤中汞0
Hg (g)Hg (g)Hgp

惯 性分离器粗灰中汞
底渣中汞
脱硫石膏中汞

70

80
除 尘 器脱除灰中汞

70

60

60

50

电厂 5

40

200 MW
PC, FF

电厂 4

30

电厂 1

电厂 2

20

220 MW
PC, ESP

600 MW
PC, ESP,FGD

50

50 MW
PC, FF电厂 6

40

135 MW
CFB, ESP

30
20

口
入

SP

口

出
口
锅
炉
入
口
E

FF

入

FF

口

出
口
锅
炉
入
口

FF

入

FF

出
口
锅
炉
入
口

口

P
ES

入

入

SP

D
FG

P
ES

SP

口

P
ES

入

入
P
ES

锅
炉

出
口
锅
炉
入
口
E

0
ESP 出口

出
口

0

口

10

出
口
锅
炉
入
口
E

10

口

单 位 时间 汞 质 量 (g/h)

2+30

APEC“清洁化石能源技术研讨会”

Cl元素 (Cl role:traditional explaination)100电 厂 1, 神华 #1
电 厂 2, 神华 #2
电 厂 3, 准格尔 #1
电 厂 4, 准格尔 #2
电 厂 5, 准格尔 #3

90

70
60
50
40
30

电 厂 2,神华 #2

2+

Hg /Hg GT (% ， 在除 尘 器 进 口 )

80

20
10
0
150

200

250

300

350

400

450

500

煤中 氯 含量 (μg/g)

31

APEC“清洁化石能源技术研讨会”碱性灰分对Hg氧化的影响(role of alkali)电 厂 1, 神华 #1
电 厂 2, 神华 #2
电 厂 3, 准格尔 #1
电 厂 4, 准格尔 #2
电 厂 5, 准格尔 #3

80

60

40

2+

Hg /Hg GT (% ， 在除 尘 器 进 口 )

100

20

0
0

500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000

因子 C
32

APEC“清洁化石能源技术研讨会”碱性灰分对Hg氧化的影响(role of alkali)电 厂 1, 神华 #1
电 厂 2, 神华 #2
电 厂 3, 准格尔 #1
电 厂 4, 准格尔 #2
电 厂 5, 准格尔 #3

80

60

40

2+

Hg /Hg GT (% ， 在除 尘 器 进 口 )

100

20

0
0

500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000

因子 C
33

APEC“清洁化石能源技术研讨会”

Contents(内容）New developments in the PM formationin the urban area（城市PM形成的新机制）
Coal combustion and PM formationfrom Power plant（煤燃烧与颗粒物形成）
Mercury pollution from Power plant（电厂汞污染形成）
Research on control methods of PM（PM控制方法研究）
Conclusions（结论）34

APEC“清洁化石能源技术研讨会”

1颗粒过滤特性的研究
主要内容

荷电颗粒过滤特性的研究

建立了从颗粒进入Kuwabara场到沉积在纤维和颗粒上全过程的运动模型。
采用Monte -Carlo 法进行了数值研究和分析。

中和颗粒在纤维上的沉积

极化颗粒在纤维上的沉积簇状沉积

直链遮挡其他颗粒沉积35

APEC“清洁化石能源技术研讨会”

1颗粒过滤特性的研究
主要内容

荷电颗粒过滤特性的研究
不同预处理颗粒滤料过滤模型的研究

由于清洁期和堵塞期的特点，建立的清洁和堵塞期过滤模型由纤维直接捕获颗粒模型，颗粒直链链尖捕捉模型和颗粒簇捕捉模型等组成。

中和工况和荷电工况穿透率变化
36

APEC“清洁化石能源技术研讨会”

1颗粒过滤特性的研究
主要内容

荷电颗粒过滤特性的研究
不同预处理颗粒滤料过滤模型的研究

由于清洁期和堵塞期的特点，建立的清洁和堵塞期过滤模型由纤维直接捕获颗粒模型，颗粒直链链尖捕捉模型和颗粒簇捕捉模型等组成。

中和工况由于能够直接形成颗粒簇，
颗粒簇随着颗粒沉积的增多捕捉能力迅速提高，使得较多的颗粒在滤料浅层沉
积而使得其最上层更早的达到填充极限，开始向颗粒层过渡。这解释了实验
中静电工况堵塞期较长的原因。

最终时刻滤料各层沉积质量37

APEC“清洁化石能源技术研讨会”

1颗粒过滤特性的研究
主要内容

荷电颗粒过滤特性的研究
不同预处理颗粒滤料过滤模型的研究

在对颗粒受力分析的基础上，建立了不可压缩颗粒层的形成模型和颗粒层的坍塌模型，并采用Monte -Carlo 法进行了数值模拟。

颗粒层形成过程数值模拟
38

APEC“清洁化石能源技术研讨会”

1颗粒过滤特性的研究
主要内容

荷电颗粒过滤特性的研究
不同预处理颗粒滤料过滤模型的研究

在对颗粒受力分析的基础上，建立了不可压缩颗粒层的形成模型和颗粒层的坍塌模型，并采用Monte -Carlo 法进行了数值模拟。
颗粒层坍塌过程数值模拟

颗粒层的压降存在脉动性，且过滤速度越高，压降越大，变化率也越大。

39

APEC“清洁化石能源技术研讨会”

主要内容

2.3 燃烧过程中颗粒物的形成和控制

针状电极产生的电场对火焰高度的影响荷电颗粒过滤特性的研究
电场对碳烟颗粒沉积特性的影响

平板电极产生的电场对火焰高度的影响主要推论：针状电极：火焰中部由于同时存在荷电及中性颗粒而电阻增大。
平板电极：火焰尖端偏向负电极，中部偏向正电极，说明较大颗粒多荷正电。
40APEC“清洁化石能源技术研讨会”

主要内容

Flame height H [mm]2.3 燃烧过程中颗粒物的形成和控制

40
38
36
34
32
30
28
26
24
22
20
18
16
14
12
10
8
6

CH4: 0.25 L/min, Air: 2.5 L/min荷电颗粒过滤特性的研究
电场对碳烟颗粒沉积特性的影响

Wire-Cylinder-type electrode实验证明：1、一部分碳烟颗粒本身荷正电荷，并会因此root (-)
root (+)
middle (-)
middle (+)
top (-)
top (+)
0

1

2

3

4

5

6

7

8

9

10 11 12 13 14 15 16 17

Applied voltage V [kV]环形电极产生的电场对火焰高度及宽度的影响受到电场力的直接作用。
2、环形电极实验证明，火焰中上部较大碳烟
颗粒多荷正电。火焰高度最大降幅73.7%。
3、TEM实验证明，荷电与否只影响颗粒团聚
尺寸，不影响一次颗粒尺寸，且在此实验中，
凝并速度小于团聚速度。

41

APEC“清洁化石能源技术研讨会”

主要内容

2.3 燃烧过程中颗粒物的形成和控制

荷电颗粒过滤特性的研究
电场对碳烟颗粒沉积特性的影响

激光诱导白炽光实验42

APEC“清洁化石能源技术研讨会”

主要内容

2.3 燃烧过程中颗粒物的形成和控制

荷电颗粒过滤特性的研究
电场对碳烟颗粒沉积特性的影响

43

APEC“清洁化石能源技术研讨会”

主要内容

2.3 燃烧过程中颗粒物的形成和控制

荷电颗粒过滤特性的研究
电场对碳烟颗粒沉积特性的影响

44

APEC“清洁化石能源技术研讨会”

主要内容

2.3 燃烧过程中颗粒物的形成和控制

荷电颗粒过滤特性的研究
湿式烟气脱硫装置对颗粒物的净化作用针对某电厂60万kw机组配置的喷淋式石灰石/石膏法烟气脱硫系统进出口颗粒物进行了现场采样
wFGD对颗粒物的脱除效率

日期

2＃
机组工况

wFGD入口wFGD出口飞灰浓度

飞灰浓度

mg/Nm3

mg/Nm3

％

脱除效率

23日

100％

86.11

21.30

75.3

26日

100％

52.65

22.70

56.9

28日

100％

84.70

22.34

73.6

29日

70％

18.33

6.78

63.0
45

APEC“清洁化石能源技术研讨会”

主要内容

2.3 燃烧过程中颗粒物的形成和控制

荷电颗粒过滤特性的研究
湿式烟气脱硫装置对颗粒物的净化作用

dM/ dl og( Dp) mg/ Nm3

2 #F GD原 烟 道 烟 尘 质 量 浓 度 的 粒 径 分 布

60. 0050. 00

入口（原烟道）与出口（净烟40. 0030. 00道）烟气中的飞灰颗粒均呈现出
双峰分布形态，峰值出现在1和3

20. 00
10. 00
0. 00

0. 1
第 1次

1
第 2次

10
Dp u m

7 0 %负 荷µm处。
wFGD系统出口颗粒物中细颗
粒PM2.5的比例提高到80 %，平2#FGD净 烟 道 烟 尘 质 量 浓 度 的 粒 径 分 布均质量中径也由入口处的3 µm减

25. 00dM/ dl og( Dp) mg/ Nm3

少到0.9 µm。

20. 00
15. 00
10. 00
5. 00
0. 00

0. 1
第 1次

第 2次

第 3次

1

70%负 荷

Dp um

10

46

APEC“清洁化石能源技术研讨会”

Contents(内容）New developments in the PM formationin the urban area（城市PM形成的新机制）
Coal combustion and PM formationfrom Power plant（煤燃烧与颗粒物形成）
Mercury pollution from Power plant（电厂汞污染形成）
Research on control methods of PM（PM控制方法研究）
Conclusions（结论）47

APEC“清洁化石能源技术研讨会”

Conclusions（结论）PM from combustion is the main issue in urban PM
pollution. New PM formation mechanism is foundPMs from different combustion sources have different
characteristics
A new Hg oxidization mechanism is foundNew control methods are needed to reduce the PM
pollution and several new directions have been formed48

APEC“清洁化石能源技术研讨会”

Acknowledge
科技部：燃烧源可吸入颗粒物的形成与控制技术基础
研究 2002CB211600
清华大学、北京大学、天津大学、华中科技大学、东
南大学和中国环境科学研究院等6个单位共同参与
研究。

中国环境科学研究院

49

APEC“清洁化石能源技术研讨会”

谢谢各位专家与同仁！

50

APEC“清洁化石能源技术研讨会”

Day 2 Tuesday 16 October 2007
Session 7: Energy and Water Saving in Coal-fired Power Plant

Speech 7 US
New Technologies for Power Plant Water Conservation

Mr. Tom Dendy
Director
Global Market & Application Development
SPX Thermal Equipment & Services
USNew Technologies for Power
Plant Water Conservation
电厂节水新技术

October 16, 20072007年10月16日

Power Plant Cooling Systems
电厂冷却系统
Once-ThroughCoolingHigh Water
Withdrawal

一次排放冷却

高排水量

Air Cooled
Condensers
No WaterWithdrawal

Hybrid Cooling Systems

Cooling
Towers

混合冷却系统

冷却塔

空气冷凝器

无排水量
No WaterConsumption
不耗水
2007/10/23

Highest Water
Consumption
最耗水2Basic Cooling System Comparison
基本冷却系统比较
Dry Cooling空冷
Turbine Efficiency

Wet Cooling湿冷

Lower 较低Higher 较高

Highest 最高

Lower 较低None 无

High高Highest 最高

Lower 较低None 无

Highest 最高

Higher 较高

Lower 较低Low 低

Higher 较高

涡轮效率Power Usage
能耗

Water Usage
水耗

Footprint
占地面积

Water Treatment
水处理

Installation Cost
安装费

Maintenance Cost维护费

Hybrid Systems
2007/10/23

混合系统

3

Conventional Cooling Tower
常规冷却塔
Evaporated Water 蒸发水
10,000 T/day 吨/天Hot Water热水

Wet Fill
湿填料

Cool AmbientAir
冷空气

2007/10/23

Cool Ambient
Air
冷空气

4

Latest Hybrid Technology – Air2Air®
最新混合技术– Air2Air
Evaporated Water蒸发水
7,000 to 9,000 T/day吨/天Condensed
Water 1,000 to
3,000 T/day
冷凝水
1,000 到3,000吨/天CoolAmbient
Air

Increase motor
kW (1.3 to 2x)
增加电机
kW (1.3 to 2x)

Condensing
Media冷凝媒介
Ducting通风管冷空气Cold Water temp
same as base tower
冷水温度与
基本塔相同

2007/10/23

5Performance Expectation
预期性能500MW Coal Plant• Evaporates ~16,000 tons of water per day• 2,000 to 5,000 tons can be reclaimed as pure water

50万千瓦火力电厂• 每天大约蒸发 16,000 吨水• 每天可回收 2,000 到 5,000 吨纯水

2007/10/23

6

Testing/Validation
实验/证实



Laboratory Validation Completed – confirmed
mathematical methods

Full Scale Installation completed – plant start
operation in October 2007



Remote Monitoring and data validationcommences October 2007实验室确认完成 – 证实数学模型正确实塔安装完成 – 2007年10月电厂运行遥控监测和数据确认于2007年10月开始

2007/10/23

7

Lab Test Arrangement
实验室装置

A2A inlet air
Blower
A2A进风口鼓风机Air outlet from
A2A pack
A2A模块出风口Effluent duct from
Cooling Tower
Cell
冷却塔排气管Condensate
Collection area
冷凝水收集区

2007/10/23

8

Lab Validation of Methods实验室结果证实数学模型

Test

实验

AAHE14-2
AAHE14-6
AAHE14-20
AAHE14-27

2007/10/23

Ambient
WB/DB,(°C)
Temperature环境湿球/干球温度(°C)
18.8/22.8

Mass Balance
Condensation,
GPM

Agreementof Methods

GPM

Volumetric
Condensation,
GPM
L冷凝体积
GPM

0.578

0.573

99.1%

Spring春季

21.7/29.7

0.408

0.399

97.8%

Spring春季

23.7/29.2

0.525

0.506

96.3%

Spring春季

14.2/20.2

0.605

0.615

101.6%

Season季节Spring春季

质量平衡冷凝准确度度9Full Scale Validation实塔证实Partially funded by United States Department of EnergyCoal-fired power generation station in New Mexico, U.S.A.

Complete rebuild of single counter-flow cellConstruction completed August 2007

Plant enters outage and re-starts October 2007

部分资金由美国能源部支助

美国新墨西哥州火力发电厂

全部重建一间逆流塔

2007年8月完成

电厂2007年8月停机大修10月重新启动

2007/10/23

10Validation Cell Sketch实验塔草图

2007/10/23

11

Construction Phase
施工阶段

2007/10/23

12

Final Assembly总装配

2007/10/23

13

Web-based Monitoring
网路监控







Visual web cam– plumecondition and recirculation
视觉网路摄像机-反映现场羽雾
情况和回流

Wireless remote operating
data with satellite uplink –SPX Flash Technologies
使用SPX Flash卫星上行链路技术无线遥控收集运行数据

2007/10/23

14Performance Impact
性能冲击







Same turbine efficiency as 100% wet system
15%-30% annual water savings
Desalination operation
Applicable to mechanical draft towers only
20% to 100% increase in fan power
Reduces visible plume from cooling tower








涡轮效率等同100%湿冷系统
每年节水20%到30%
减少盐分运行只适用于机械通风冷却塔风机能耗增加20%到100%
减少冷却塔能见羽雾

500MW Coal Plant Æ 5,000 tons water per day
50万千瓦火力电厂Æ每天回收5,000 吨水
2007/10/23

15

Day 2 Tuesday 16 October 2007
Session 7: Energy and Water Saving in Coal-fired Power Plant

Speech 8 US
Integrated Strategy for Efficiency, Emissions Reductions and Safety
for Coal-fired Power Plants

Mr. Brad RadlPresident and Chief Technical Officer
Taber International LLC
US“Harmonious and Sustainable Coal
Power Generation”
APEC Clean Fossil Energy Seminar
Integrated Strategy for Efficiency, Emissions andSafe Energy Production
Clean Energy Solutions
for the Power Industry

Brad Radl, Pres. & CTO
1
Confidential Taber International Llc.

Power Plant Optimization Systems
NOx Control-SCR Systems-SCONOx-SNCR-COS

SootBlowing

Turbine Upgrades
Steam Turbine
and Generator

Comb.
Opt.

Hydrogen Cooling Opt.

Coal Pile/Fuel
Blending

Substation
Systems

Pulverizer

Cooling Water Treatment
Condition
Monitoring

Flue Gas
Desulfurization– Wet FGD
– Dry FGD
– FDA

Data Base and Data Mgt.

2
Confidential Taber International Llc.

Issues Facing Integrated Strategy• Philosphy of ‘Either – Or’ for Software andHardware.
– Software Vendors sell Software– Hardware Vendors sell Hardware• Result is many missed opportunity toextend Hardware Life, Lower Costs andfurther improve efficiency or reduce
emissions3
Confidential Taber International Llc.

Issues Facing Integrated Strategy• Islands of Automation• Particulary for Software put also the
Hardware systems.
• Rational Desire to ‘Define’ and ‘Solve’ a
problem through reduced complexity.
• Result can be competing systems• Increased Capitial and Operations Costs
4
Confidential Taber International Llc.

Opportunities Lost
• Heat Rate Potentially Can be Reduced 5%
or more on existing assets.
(e.g. 360 g/kwhr to 342 g/kwhr)• SOx can be Reduced by 95%+ while
minimizing feedstock and power• NOx can Reduced 40 to 95%, while
minimizing capital costs and extending
catalyst life
• Hazardous chemical handling can be
reduced or eliminated5
Confidential Taber International Llc.

Opportunity Lost
Virtually all units with High Automation andOrganizational Support experience• Fewer Unplanned Outages• Higher Capacity Factors• Best Heat Rates.
• Lowest Environmental Impact
Challenge is the first two items are difficult if not
impossible to quantify on a per project basis
6
Confidential Taber International Llc.

Main Barriers for Implementing
Advances Systems
Per CANMENT Survey

Other priorities
5%

Justify benefits
9%
Cost
22%

Operational
staff
5%

Lack ofresources
18%

Old equipment
18%
Lack ofinformation
14%

Lack ofexperience
9%7

Confidential Taber International Llc.

Integrated NOx Project• Fuel Switching• Low NOx Burners 1996 Design• Overfire Air Ports Installed• Combustion Optimization• Intelligent Sootblowing

8
Confidential Taber International Llc.

Summary of Potential
NOx Reduction without Post-Combustion Hardware
NOx Improvement

Results are Relative – Not Additive100% N O x re d u c tio n

80
60
Maximum Improvement

40

Minimum Improvement

20

ta
b lo
ot
So
t.
In

te

llig

en

n
Co

mb

us

t io

Lo

To

wi
ng

n
t io
i za
t im
Op

No
w

el
Fu

OF

xB

Sw

ur

it c

ne

hin

rs

g

A

-20

l

0

9
Confidential Taber International Llc.

Integrated NOx Strategy
NOx output reduced from 35000 to 4000 Tons Annually
USA MidWest Utility
Integrated Strategy for NOx Reduction
No Post Combustion Hardware
0.7

NOx lbs/m btu

0.6

Heat Rate Improved by 0.75%

0.5
0.4

Series10.3
0.2~70mg/m3

0.1
0Baseline

Fuel Switch

Low Nox Burners
w/OFA

Combustion
Optimization

Instrument
Upgrade w/ISB

Project(s)Confidential Taber International Llc.

10

Instrumentation and Equipment
Changes• Replaced O2 Sensors• Added CO Sensors• Fixed SootBlowers• Added Individual Burner Air Control
Capability with Low NOx Burners– Only later implemented DCS logic changes toallow COS tuning

Confidential Taber International Llc.

11

Additional
Results
 Reduced Furnace Exit Gas Temp by 40 DegC
 Operated continuously over a wide range ofcoal compositions
 Fuel ranges from Sub-Bituminous Powder River
Basin Coal to High Sulphur Eastern Coal

 Unplanned Outages Down Significantly

Confidential Taber International Llc.

1
2

Possible Heat Rate Integration
Software and Hardware

Confidential Taber International Llc.

1
3

Possible Heat Rate Integration
Software and Hardware• Example to Achieve:– 5% or greater HR reduction– 20% to 80% NOx reduction– 5% or greater CO2 reduction– Eliminate Cl or Br in cooling water– Reduce/eliminate hazards of chemical
production of H2

Confidential Taber International Llc.

1
4

Software
Combustion Optimization• Combustion Optimization– Improve Fuel/Air Mixing – Lower Heat Rate
– Lower NOx– Mature Technology

Confidential Taber International Llc.

1
5

Fuel Blending
Software and Instrumentation• Fuel Blending -Match best available fuel to need
– Achieve Peak Power– Lowest average emissions over daily period– Avoid FGD issues with out of spec. coal
– Burn low grade fuel, when feasible and economical• Normally requires added instrumentation andpossible fuel yard changes.
• Link Data to your Combustion Optimization and
FGD processes
Confidential Taber International Llc.

1
6

Cooling Water Treatment
with Bio Filming Agent

Confidential Taber International Llc.

1
7

Cooling Water Treatment
Consider a “Green” Alternative• “Eliminate use of Cl2 or Br oxidants• Cleaner and less Corroded Condenser Leads
to Heat Rate Improvement – often 1% to
3% through lower back pressure• Filming agent requires less dosage.
Confidential Taber International Llc.

1
8

Cooling Water Treatment

Confidential Taber International Llc.

1
9

Steam Turbine Upgrade

Retractable

Custom Fit
Confidential Taber International Llc.

20

Steam Turbine Upgrade
Typically Results in:– Reduction of clearance from 0.05 cm to an effective
clearance of 0.005 cm– Retractable packing reduces damage during start-up– Bristle flexibility allows rotor excursions at load
– Reduce tip seal losses up to 70%– 1% to 3% steam turbine efficiency gain
Confidential Taber International Llc.

2
1

Generator Efficiency
Improvement
through
Automatic Hydrogen
Control versus
Manual Feed andAdjustment

Confidential Taber International Llc.

2
2

Reduce Pressure Variance andImprove Average Purity Levels• Pressure Variance reduced by 10x• Average Purity Levels raised 0.8%
• Pressure Alarms in control room eliminated• Generally gain min. 100kw/100MW ofgeneration through windag loss reduction
alone• Possible additional gains from cooling
Confidential Taber International Llc.

2
3

Improved Hydrogen Supply• 99.999% Pure Hydrogen• - 65 DegC Dewpoint• On-Site Supply source

Confidential Taber International Llc.

2
4

Benefits• Lower Windage and Core Losses leads to:– Increased kW output of generator, or– Decreased coal consumption for same MW out• - 65 DegC Dewpoint leads to:– Less corrosion of generator components• Combined with Automatic Control can extend
Generator Maintenance period• No caustic chemicals – Eliminate KaOH process(Capital savings for new plants)• Inherently safe operation Avoid capital costs Off-site production facilities
Confidential Taber International Llc.

25

Summary of Potential
Heat Rate Improvement

Results are Additive% Heat Rate Improvement

12
10

For example: Unit starting at 350 g/kWh could be
reduced to between 313 and 341 g/kWh

8Max. Imp

6

Min. Imp.

4
2
0
Fuel
Blending

COS

Filming
AgentsConfidential Taber International Llc.

Steam
TurbineUpgradeH2 Auto H2 Purity
Total
Control
Potential
HR Imp2
6

Timeframes and Costs• Cooling Water and Hydrogen (whereapplicable) require no outages and are low
cost.
• Combustion Optimization and Fuel
Blending are moderate cost and may require
short outages (<3 days) for DCS changes or
equipment installation• Steam Turbine Upgrades are mostexpensive but offer the guaranteed gains.
Confidential Taber International Llc.

2
7

Software Integration
Many Application Areas Available• Combustion Optimization• CFB Optimization• FGD Optimization• SCR Optimization• Intelligent Sootblowing• Pulverizer Optimization and Diagnostics• Fuel Blending• Dispatch Optimizer• Steam Temperature Optimization
Confidential Taber International Llc.

2
8

Conclusion
Q&A
Thank you for your time
For More Information or Copies of this Presentation
Please Send E-mail to
RADL@TABER-INTL.com
Confidential Taber International Llc.

2
9

Day 2 Tuesday 16 October 2007
Session 7: Energy and Water Saving in Coal-fired Power Plant

Speech 9 PR China
Problems in Condensate Polishing System of Direct Air-Cooled Unit
and Its Solutions

Dr. Tian Wenhua
Thermal Power Research Institute (TPRI)PR China

TPRI

TPRI

直接空冷机组凝结水精处理存在问题及解决对策Problems in Condensate Polishing System of
Direct Air-cooled Unit and its Solutions

田文华Tian Wenhua

西安热工研究院
Xi’an Thermal Power Research Institute Co Ltd.

TPRI

主要内容
一. 前言
二. 我国直接空冷电厂概况
三. 阳阴分床与粉末树脂覆盖过滤器性能比较
四. 空冷机组凝结水精处理存在问题五. 解决对策
六. 结论

TPRI

CONTENTS
I. Preface
II. Introduction of direct air-cooled unit in China
III. Comparison of performance between cationanion separated bed and powdered resin filter
IV. Problems in condensate polishing system of
direct air-cooled unit
V.

Solutions

VI. Conclusion

TPRI

前言

¾ 截至2006年10月，国内已经投产的直接空

冷机组有2台200MW机组，10台300MW机组，8台600MW机组¾ 预计到2010年，国内将有40余座空冷电站
投产，总装机容量将达到40000MW
9与湿冷机组相比，空冷系统的冷却面积大，凝结水中的腐蚀产物多，9与湿冷机组相比，空冷系统的冷却面积大，凝结水中的腐蚀产物多，水质更不容易控制。而国内目前对大型直接空冷机组凝结水精处理研
水质更不容易控制。而国内目前对大型直接空冷机组凝结水精处理研究较少，超临界空冷机组国内还没有投运机组，缺乏经验。
究较少，超临界空冷机组国内还没有投运机组，缺乏经验。
9因此，对已经投运的大型直接空冷机组凝结水精处理存在的问题进行
9因此，对已经投运的大型直接空冷机组凝结水精处理存在的问题进行
分析与总结，对提高我国空冷机组凝结水精处理的设计和运行水平有分析与总结，对提高我国空冷机组凝结水精处理的设计和运行水平有
重要意义。
重要意义。

TPRI

Preface¾ There are 2 units of 200MW, 10 units of 300MW

and 8 units of 600MW of direct-air-cooled units inservice until Oct. 2006
¾ It is estimated that more than 40 direct-air-cooled
power plants will be in service until 2010 and thetotal capacity will reach 40000MW in China
9Compared
9Compared with
with wet-cooled
wet-cooled unit,
unit, air-cooled
air-cooled unit
unit has
has large
large cooling
cooling area
area
and
andso
somuchmuchcorrosive
corrosiveproducts
productsinincondensate
condensatewater
waterthatthatits
itswaterwaterquality
qualitycancannotnoteasily
easilybe
becontrolled.
controlled.Moreover,Moreover,thethelarge
largedirect-air-cooled
direct-air-cooledunit
unithashas
been
been little
little studiedstudied inin ourour country
country andand thethe super-criticalsuper-critical unit
unit has
has not
not been
been
operated
operatedandandno
noexperience.
experience.
9Thus,
9Thus, itit isis very
very important
important toto analyze
analyze andand summarize
summarize thethe problems
problems inincondensate
condensatepolishingpolishingof
ofdirect-air-cooled
direct-air-cooledunit
unitthat
thathashasbeenbeenininservice.
service.

TPRI

我国部分已投产的直接空冷电厂概况

序
号

项目名称

装机容量

机组形式

投产时
间

凝结水
精处理方式

1

山西漳山发电有限责任公司

2×300MW亚临界

2004.8

阳阴分床2

华能榆社电厂

2×300MW亚临界

2004.10

阳阴分床3

山西大唐国际云冈热电公司

2×220MW

亚临界

2004

阳阴分床

9

达拉特电厂四期

2×600MW亚临界

2006.12

粉末树脂过滤
器10华能铜川电厂

2×600MW亚临界

2007.6

粉末树脂过滤
器•机组的容量越来越大，参数越来越高。目前已经投运的•机组的容量越来越大，参数越来越高。目前已经投运的
4
2×600MW 亚临界直流
2005.4国电大同发电公司
粉末树脂过滤
主要以300MW、600MW亚临界机组为主，在建的以600MW亚
炉器
主要以300MW、600MW亚临界机组为主，在建的以600MW亚
5临界为主，华能上安电厂是我国首个600MW超临界空冷机
4×600MW 亚临界汽包
2005.9大唐托克托电厂三、四期
阳阴分床
临界为主，华能上安电厂是我国首个600MW超临界空冷机炉组
6组 华能北方电力上都电厂
8×600MW 亚临界
2006.8
粉末树脂过滤
•凝结水精处理方式中阳阴分床和粉末树脂覆盖过滤器各器•凝结水精处理方式中阳阴分床和粉末树脂覆盖过滤器各72×300MW 亚临界
2006
华能乌拉山电厂
粉末树脂过滤
占一半左右。近年来粉末树脂覆盖过滤器的比例有上升
占一半左右。近年来粉末树脂覆盖过滤器的比例有上升器
趋势8趋势
2×600MW 亚临界
2006.10国华锦能公司一期
阳阴分床

TPRI

Parts of direct air-cooled plants in service in China
序
号

项目名称

装机容量

机组形式

投产时
间

凝结水
精处理方式

1

山西漳山发电有限责任公司

2×300MW亚临界

2004.8

阳阴分床2

华能榆社电厂

2×300MW亚临界

2004.10

阳阴分床3

山西大唐国际云冈热电公司

2×220MW

亚临界

2004

阳阴分床

4

国电大同发电公司

2×600MW亚临界直流2005.4

粉末树脂过滤

8

国华锦能公司一期

2×600MW亚临界

2006.10阳阴分床9达拉特电厂四期

2×600MW亚临界

2006.12

粉末树脂过滤
器10华能铜川电厂

2×600MW亚临界

2007.6

粉末树脂过滤
器•The
more large and the pressure•Theunit
unitcapacity
capacitybecome
becomemore
moreandand
炉 more large and the
器 pressure
become more
The
composedof
moreand
andmoremorehigh.
high.
Theservice
serviceunits
units
composedofmainly
mainly5 become
4×600MW2005.9大唐托克托电厂三、四期
亚临界汽包
阳阴分床
300MW
and the constructed units are
300MWandand600MW
600MWsub-critical
sub-criticalunits
units
炉 and the constructed units aremainly 600MW.
HuanengShang’anPower
600MW.Up
Upto
tonow,
now,
HuanengShang’anPowerPlant
Plantisisthe
thefirst
first
6 mainly
8×600MW
2006.8华能北方电力上都电厂亚临界粉末树脂过滤
super-criticalsuper-criticalair-cooled
air-cooledunit
unitofof600MW.
600MW.
器•Cation-anion
separatedbed
andpowderedresinfiltersharedseparated bed
and powderedresinsharedhalf
halfofof
7 •Cation-anion
2×300MW2006 filter
华能乌拉山电厂
亚临界
粉末树脂过滤
quotient
filterquotientrespectively.
respectively.But
Butthetheratio
ratioofofpowdered
powderedresin
resin器filtershows
showsaaincreaseincreasetrend.
trend.

阳阴分床与粉末过滤器性能比较
TPRI
Comparison of the performance of separated bed
and powdered resin filter项目阳阴分床系统

粉末树脂覆盖过滤器系统

系统
组成每台机组由 2 ×50 %的高速阳床和
2 ×50 %的高速阴床组成，不设备
用。阳床或阴床各自配 1 套旁路系
统每台机组设置 1 套 2×100 %粉末树脂
覆盖过滤器系统, 并设置 100 %的旁
路。系统由粉末树脂覆盖过滤器系统、
旁路系统、爆膜清洗及铺膜系统、压缩空气系统、废水收集及输送系统等组成

解列条件

当精处理装置压差大于 0.35 MPa
时, 旁路阀门全开；进水温度高于 65℃时阴床旁路阀自动全部打开, 进
水温度高于 75 ℃时阳床旁路阀自动
全部打开

当精处理装置压差大于 0.75 MPa 时,
自动打开旁路阀门；进水温度高于 70℃时旁路阀自动全部打开系统结构1）过滤与吸附能力大大优于常规混床2）失效后不需再生
3）运行方式灵活。可根据进水水质选
择铺膜材料、配比及其使用剂量
4）降低了运行水耗5）设备简单, 不需要再生系统及再生废
液处理设备、投资省

9Both
9Both have
have its
its advantages
advantages andanddisadvantages.
优点disadvantages. But
But thethe cationcation9两者各有优缺点，但综合比较，
9两者各有优缺点，但综合比较，anion
运行anion separated
separated bed
bed isis moremore阳阴分床更适合直接空冷机组。
特点阳阴分床更适合直接空冷机组。
suitablesuitable forfor thethe direct-air-cooled
direct-air-cooled
1）基本没有除盐能力，出水水质不能units.
1）除铁能力较差units.
满足要求
1）出水水质指标好2）对水温变化有灵活的调节方式
3）装填的树脂量是粉末树脂的近 20倍，化学除盐作用强4）树脂可反复再生，运行费用低缺点2）系统复杂, 占地面积大，投资费
用高, 操作复杂, 再生时间长2）粉末树脂不能重复使用，运行费用高TPRI
大唐托克托电厂（8×600MW，内蒙）Datang Tuoketuo Power Plant（Inner Mogolia）

TPRI＃5机高速阳床
Unit 5 high-flowrate cation bed

TPRI达拉特电厂（8×600MW）
Dalater Power Plant （Inner Mogolia）

TPRI

粉末树脂覆盖过滤器
Powdered resin filter

TPRI

国华锦界电厂阳阴分床系统
Separated bed in Jingjie power plant（4×600MW,Shaanxi）

TPRI

600MW直接空冷机组凝结水精处理进、
出水水质情况（2007年）
名称
测试
项目

进水
温度
（℃）

出水

CC
μs/cm

O2
μg/L

CC
μs/cm

SiO2
μg/L

Na+
μg/L

≤0.3

≤30

≤0.2

≤15

≤5

测定日期

工艺

0.5~1.3

3.5

阳阴分床5#机 29~37 0.09~0.12 30~56 0.08~0.10 2.1~3.8

－

4.23

7#机 38~49 0.10~0.20 6～47－

标准值A 厂 1#机 35~49 0.16~0.21 40~100 0.13~0.16 2.8~4.4B厂C 厂 7#机 47~56 0.10~0.13

15

0.06

3.7~3.8

0.07~0.09 12~19 0.12~0.21

出水SiO
出水SiO22超过标准
超过标准

阳阴分床

4.23
3.20

粉末树脂

TPRI
The influent and effluent water quality in condensate
polishing system of 600MW direct-air-cooled units（2007）
Contents

Influent

Analyzed Item

Temprature（℃）

Standard Value
Plant A

Eflluent

CC
μs/cm

O2
μg/L

CC
μs/cm

SiO2
μg/L

Na+
μg/L

≤0.3

≤30

≤0.2

≤15

≤5

Date

Process

Separated Bed

1# unit

35~49

0.16~0.21

40~1000.13~0.16

2.8~4.4

0.5~1.3

3.5

5#unit29~37

0.09~0.1230~56

0.08~0.10

2.1~3.8－

4.23

7#unit38~49

0.10~0.20

6～47

0.06

3.7~3.8－

4.23

7#unit47~56

0.10~0.13

15

0.07~0.09

12~19

0.12~0.21

3.20

Plant B

Plant C

Separated Bed

SiliconSiliconin
ineffluent
effluent
surpassed
surpassedthe
thestandards
standards

Powered Resin Filter

TPRI

空冷机组凝结水精处理存在问题（1）¾ 在系统设计中对空冷系统的特点认识不够

全面，片面认为空冷系统中没有盐类物质
的漏入，因此主要是除铁，使用粉末树脂
过滤器就可达到要求，忽视了空冷系统凝
结水的除盐问题，导致出水二氧化硅和二
氧化碳超标。
9实际上，空冷系统水汽接触的换热表面积极大，凝结水中
9实际上，空冷系统水汽接触的换热表面积极大，凝结水中COCO22含量很高，CO含量很高，CO22溶于水后会消耗掉粉末树脂过滤器本来
溶于水后会消耗掉粉末树脂过滤器本来
就很小的交换容量。另外，由于空冷系统庞大，在安装过程就很小的交换容量。另外，由于空冷系统庞大，在安装过程中带入的灰尘、砂石和基建垃圾不能彻底清除，在机组启动
中带入的灰尘、砂石和基建垃圾不能彻底清除，在机组启动过程中大量的铁、盐类杂质和硅的化合物穿过粉末树脂覆盖过程中大量的铁、盐类杂质和硅的化合物穿过粉末树脂覆盖过滤器进入热力系统，造成机组投运过程中水汽品质不合格过滤器进入热力系统，造成机组投运过程中水汽品质不合格，给机组的安全稳定运行带来诸多隐患。
，给机组的安全稳定运行带来诸多隐患。

TPRI

Prolblems(1)¾ The

designer did not understand thecharacteristics of air-cooled systems
entirely. They thought that there is no
9Actually，the
heat
area
is
and
salts leakage
in thesystemandthelarge
main
9Actually，theheat transfer
transferarea ofof water-steam
water-steam
is very
very
large
and
the
carbondioxideconcentration
is
so
high
that
ititwill
consumeupthegoalcarbonindioxideconcentration
is
so
high
that
will
consumeuppolishingsystemistoremoveirons,
thethe little
little ion
ion exchange
exchange capacity
capacity ofof powdered
powdered resin
resin after
after dissolved
dissolved
in
In
dust,
garbage
can
be
so
resin
filterandcanobtainthein water.
water.powdered
In addition,
addition, thethedust, sands
sands
and
garbagecan notnotbecleanedcleaned up
up completely，socompletely，so iron,
iron, salts
salts andand siliconsilicon will
will penetrate
penetraterequirements
andsalt
removewaspowdered
powdered resin
resin filter
filter andand enter
enter into
into thermal
thermal power
power systemsystem at
at thethestart.
So
start.
So thethe waterwater andand steamsteam quality
quality will
will surpass
surpass thethe standards
standards
neglected.
and it will lead to safety problems.
and it will lead to safety problems.

TPRI

空冷机组凝结水精处理存在问题（2）¾ 空冷机组凝结水精处理系统进水溶氧普遍超标
9按标准要求，挥发处理时，凝结水处理装置前凝结水溶解9按标准要求，挥发处理时，凝结水处理装置前凝结水溶解氧浓度应小于30μg/L，但由于空冷系统水汽接触的换热表面氧浓度应小于30μg/L，但由于空冷系统水汽接触的换热表面
积大，凝结水中O
积大，凝结水中O22含量较高，经常达不到这一标准，如表2中含量较高，经常达不到这一标准，如表2中A厂凝结水溶解氧达40~100μg/L
A厂凝结水溶解氧达40~100μg/L

TPRI

Prolblems(2)¾ Dissolved oxygen in influent of air-cooled

unit condensate polishing system always
surpassed
the standard
9
Dissolved
oxygenin
9Dissolved
oxygenin influent
influent ofof condensate
condensate polishingpolishingsystemμg/L(AVT) according
system should
should be
be below
below 3030μg/L(AVT)
according toto thethestandard.
standard. Actually,
Actually, thethe dissolved
dissolved oxygen
oxygen concentration
concentration
alwaysalways exceed
exceed this
this value
value forfor thethe large
large heat
heat transfer
transferarea.
μg/L inarea. ForFor example,
example, DO
DO waswas 40~100
40~100μg/L
in Plant
Plant AA ofof
table
table22

TPRI

空冷机组凝结水精处理存在问题（3）¾ 由于空冷系统夏季凝结水温度过高，使用阳阴分床系统的电厂凝结水不能直接进入处理系统，造成夏季精处理投运率低
9尤其是对亚临界直流炉及超临界空冷系统，这一问题将更9尤其是对亚临界直流炉及超临界空冷系统，这一问题将更
加突出
加突出

TPRI

Prolblems(3)¾ The condensate water can not enter thecation-anion separated polishing system
directly for the temperature exceed thestandard and the service rate is very lower
in summer
9The
9The problems
problems will
will bebe moremore severe
severe forfor sub-critical
sub-criticaldirect-flow
direct-flowboiler
boilerand
andsuper-criticalsuper-criticalair-cooled
air-cooledsystems
systems

TPRI

亚临界和超临界机组凝结水精处理出水水质要求对照项目氢电导率（25℃）μs/cm
挥发处理

亚临界
超临界

铁
μg/L

铜
μg/L

钠
μg/L

氯离子
μg/L

≤15

≤8

≤3

≤5

-

≤10

≤5

≤2

≤3

≤3

加氧处理

≤0.2
<0.15

二氧化硅
μg/L

<0.12

9可见超临界机组对水汽品质的要求更为严格，现有的某些
9可见超临界机组对水汽品质的要求更为严格，现有的某些
精处理方式虽然能够达到亚临界机组的水质要求，但未必能精处理方式虽然能够达到亚临界机组的水质要求，但未必能满足超临界机组的水质标准满足超临界机组的水质标准TPRIComparison of water quality of condensate
polishing effluent between sub-critical and supercritical unit
CC（25℃）μs/cm

Item
AVT

Super- critical

<0.15

Fe
μg/L

Cu
μg/L

Na
μg/L

Clμg/L

≤15

≤8

≤3

≤5

-

≤10

≤5

≤2

≤3

≤3

OT
≤0.2

Sub-critical

SiO2
μg/L

<0.12

9The
9The table
table shows
shows thatthat steam
steam andand waterwater quality
quality ofofsuper-criticalsuper-critical unit
unit isis moremore stringent,
stringent, so
so somesomecondensate
condensate polishingpolishing processprocess which
which isis suitable
suitable toto subsubcriticalcriticalunit
unitwill
willnot
notfitfitforforsuper-criticalsuper-criticalunit.
unit.

TPRI

空冷机组凝结水精处理存在问题（4）¾ 使用粉末树脂覆盖过滤器的电厂，运行成本很高

9在投运初期由于大量杂质进入粉末树脂覆盖过滤器造成频
9在投运初期由于大量杂质进入粉末树脂覆盖过滤器造成频
繁爆膜，运行费用大大增加。这一过程持续时间较长，一般
繁爆膜，运行费用大大增加。这一过程持续时间较长，一般
达半年甚至一年以上。
达半年甚至一年以上。

TPRI

Prolblems(4)¾ The operation expense is very high in

power plant using powered resin filter

9The
9The operation
operation expense
expense will
will bebe very
very highhigh at
at thethebeginning
beginning forfor large
large amounts
amounts ofof dirty
dirty enter
enter into
into thethepowdered
powdered resin
resin filter.
filter. This
This course
course will
will continue
continue forfor aalong
longtime
timeeven
evenhalf
halfyear
yearsosomuchmuchasasone
oneyear.
year.

TPRI

解决对策

¾ 对已投运的空冷机组进行系统总结，对系统的优化配置方式进行深入研究¾ 尽早发布空冷机组设计、运行的技术规范
和要求¾ 对亚临界直接空冷机组目前运行中存在的问题及超临界直接空冷机组可能遇到的问题进行专题研究，及早提出解决办法

TPRI

¾ To

Solusionssummarize the air-cooled units inservice and to study the optimal configurestyle¾ To put forward the design and operation
guidelines and requirements of air-cooled
unit and to instruct the design,commissioning and operation¾ To study the problem of super-critical unit
earlierTPRI结论¾ 粉末树脂覆盖过滤器只能起到过滤除铁的作用，不能除去系统中的盐类杂质、硅的化合物及CO2等，不适合单独作为空冷系统凝结水精处理设备¾ 存在的问题有：设计不够合理、夏季高温时投运
率低、粉末树脂覆盖过滤器运行成本高等¾ 解决对策是：对已投运的空冷机组进行系统总结，对系统的优化配置方式进行研究，尽早制订
空冷机组设计及运行技术规范。对亚临界直接空
冷机组目前运行中存在的问题及超临界直接空冷
机组可能遇到的问题应进行专题研究，及早提出
解决办法

TPRI
¾ Powdered

Conclusion

resin filter can only remove irondeposits by filtering but can not remove salts,
silicon and dioxide carbon in the polishingsystem, so it is not suitable as the treatment
equipment of condensate polishing separately¾ The condensate polishing system in direct aircooled unit has the disadvantages of poor
system design, low operation rate in summer,
high operation cost of powdered resin filter andso on¾ The suggested solutions are to study the optimal
configure style, to put forward the guidelines ofdesign and operation, to study the problems ofsuper-critical unit earlier

TPRI

Thanks！

Day 2 Tuesday 16 October 2007

Session 8:
FBC/ USC/ IGCC/ CCSDay 2 Tuesday 16 October 2007
Session 8: FBC/ USC/ IGCC/ CCS

Speech 1 Australia
An Overview of post-combustion CO2 Capture at CSIRO

Dr. Paul Feron
CEO Science Leader
CSIRO Energy Technology
Commonwealth Scientific and Industrial Research Organization (CSIRO)
Australia

Post-combustion CO2 capture R&D at CSIROAPEC Clean Fossil Energy Seminar
Paul H.M. Feron
Xian, 15-17 October 2007

Overview¾¾¾¾

Introduction
Climate Change
CO2 Emission reductions & CCS
Post-Combustion Capture (PCC)••

IssuesTechnology potential¾ PCC programme at CSIRO••

Research activities
Pilot activities¾ Acknowledgements

CSIRO Energy Technology• 6 500 researchscientists/engineers andsupport staff• 56 sites around the country
and abroad• Division of Energy
Technology:• Renewables• Low emission fossil
fuels• Energy storage• Distributed energy
management and supply

Quotes from Intergovernmental Panel on Climate
Change (Work in Progress!)

IPCC AR4: Working Group I (The PhysicalScience Basis) Summary for Policymakers:¾"Warming of the climate system is unequivocal."¾"Most of the observed increase in globally
averaged temperatures since the mid-20th
century is very likely due to the observed
increase in anthropogenic greenhouse gas
concentrations."Lowering CO2-emissions
Lowering the carbon intensity of our society:¾ Switching from coal to gas¾ Improve energy efficiency¾ Extend use of renewable energy¾ Extend use of nuclear energy

Carbon dioxide capture and storage (CCS) is
valuable addition to this portfolio:¾ Allows continued use of fossil energy sources in a carbon
constrained environment¾ Buys time for transition to sustainable energy systems

Emission reduction pathway for Australia
500

Efficiency(10%)

Energy Management450&
ienc yy eff ic
Energ

400

s truct...

Electricity
decentral(20%)

Distributed generation

350

Renewables

Mt CO2e300
Fossil and nuclear

250
200

Alt
e rn
ativ
e

150

fue
ls &

Re
d

100

veh
icle
s

uce
dt
rav
el

Electricity
central(50%)

Transport(20%)

50
50% below 1990 emission levels
0
2000

2010

2020

2030

2040

2050

Source: Energy Futures, Paul Graham, CSIRONear zero-emission technologies
air

PF Power Plant
fuelenergyconversion

CO2
separation

power

CO2

flue gas

CO2-N2 separation)

air

fuel

fuel
conversion(Post-combustion

air

CO2
separation

H2

IGCC

energyconversion

flue gas(Pre-combustion
CO2-H2 separation)

power

CO2

fuel

Oxy PF Power Plant
air

air
separation
N2

O2

energyconversion
CO2

power

(Denitrogenation O2/N2 separation)

Maturity of CCS technology
Post-combustion
Oxyfuelcombustion

Mineralcarbonation
Ocean storage

Researchphase

Pre-combustion

Industrial
separation

Transport
Enhanced
Coal Bed
MethaneDemonstrationphase

Gas and oilfieldsIndustrial
utilization

Salineformations

Enhanced Oil
RecoveryEconomicallyfeasible under
specific conditions

Maturemarket

IPCC special report on CO2 capture and storage

Challenges for CO2 capture

Capture of CO2 can be done withtechnologies presently available but:
¾ Sizeable efficiency reduction¾ Power generation costs will increase¾ There is no experience with CO2 capture
integrated at the power plant scale

Why prefer Post-Combustion CO2 Capture?

¾Low technology risk
¾Flexible operation, in tune with market
requirements¾Ability to adopt technology
improvements, providing pathway
toward zero-emissions¾For new and retrofit applications,preventing stranded assets

PCC application in Australian coal fired power stations¾Generation capacity ~ 28 GW¾Electricity production 170 TWH/a¾Average generation efficiency• Black coal: 35.6% - 0.9 tonne CO2/MWh• Brown coal: 25.7% - 1.3 tonne CO2/MWh¾CO2-emissions ~ 170 Mtonne CO2/a from ~ 60 flue gas streams¾SO2 levels:• Black coal: 200 - 600 ppm• Brown coal: 100 - 300 ppm¾NOx levels:• Black coal: 300-700 ppm• Brown coal: 100-200 ppm¾Cooling water: 1.5-3.0 m3/MWh¾Typical flue gas stream: ~2.5 106 m3/h at 120 oC (0.5 GW)
Data used from CCSD – technology assessment report 62

PF Power Plant with PCC

Generator

BoilerLiquid CO2

Electricity
Low CO2 flue gas
Absorber

Coal

CO2

StripperFlue gas
pretreatme
nt
C.W.

Fly-ashFlue Gas

Leading option is a solvent process

ReboilerSolvent process diagram
CO2

Absorber

StripperFlue gas
pretreatment

C.W.

Flue Gas

ReboilerKnown issues with PCC¾ High cost: around $30/t CO2 captured¾ Electricity cost increase from $30/MWh to$50/MWh for an 85% reduction in GHG¾ Loss of generation efficiency around 2030% to capture 90% of CO2¾ Not demonstrated in integrated power
plants scale¾ Sensitive to O2, SOx and other flue gas
constituents¾ Large increase in cooling water requirement

Relevant cost factors

Electricity
cost increase

CapitalGas path related

Other equipment

Operation

EnergyOther

Resulting in prioritisation for solvent process development

Typical volume flows in absorption process
Vented Gas

Flow~0.05

Condenser

CO2 –ProductFlow~0.004

Flow~0.2
100ºC

P=1 bar
P=1 bar

Absorber

HTX

T=50ºC
T=50ºC

P=1.8 bar

DesorberFlow~0.3

120ºC

Flow~1

Flue Gas In

Flow~0.00013

P = 110 bar

Solvent system development

Solvent - chemistry
Process design - flow sheet
Equipment - hardware
Integration - thermodynamics

A holistic approach is essential!

Integrated PCC R&D Programme
Pilot plant programme (Learning by doing)¾ Hands-on experience for future operators¾ Identification of operational issues and requirements¾ Testing of existing and new technologies under realconditions

Lab research programme (Learning by searching)¾ Support to pilot plant operation and interpretation of
results¾ Develop novel solvents and solvent systems which
result in lower costs for capture¾ Addressing Australian specifics (flue gases, water)

Development Pathway for PCC
Current best technology
Generation I: MEA(chemicals)$/t CO2

Generation II: Improved “MEA”(EOR, chemicals)

Generation III: Novel solvents(PCC-CS)
Generation IV: Novel capture systems(PCC-CS)

//
1930

2000

2010

Focus of the lab research

2020

PCC Technology Development Scenario
Contribution CO2 binding
Thermal energy requirement [Gj/ton CO 2 ]5.0

Contribution steam stripping

Contribution solvent heating

State of the art

4.0

3.0

Improvement
Potential

2.0

1.0

0.0
G1

G 1/2

G 2/3
Technology development

G 3/4

G4

Efficiency no capture

Efficiency with capture

Emissions no capture

Emissions with capture

0.60

2.40

Efficiency reduction

2.20

0.40

2.00
1.80

0.20

1.60

State of the art

1.40

0.00

1.20

G1

G 1/2

G 2/3

G 3/4

-0.20

G4

1.00
0.80
0.60

-0.40

CO2 Emission reduction

0.40
0.20

-0.60

0.00

Technology development

CO2-emissions [ton/MWh]

Generation Efficiency

Efficiency and CO2 Emissions

Cooling water issues

3

Cooling water requirement [m /MWh]

No Capture

90% Capture

6.00
G1

Increase in cooling water
5.00
4.00
G 1/2
3.00

State of the art

G1

G 2/3
2.00

G 1/2
G 2/3

G4
G4

1.00
0.00
0.00

0.10

0.20

0.30

0.40

0.50

0.60

CO2-emission [ton/MWh]

0.70

0.80

0.90

1.00

Basic Chemistry Gl/ll
2R-NH2 + CO2
(MEA)

Ù

• Advantages of MEA• Very fast reaction• Efficient absorption of CO2• Amine is relatively cheap

R-NH3+ + R-NH-COO(Carbamate)• Disadvantages of MEA• Carbamate is very stableªHigh energy ofregeneration• 2 moles of amine required permole of CO2 (2:1 ratio)• Amine undergoes oxidative
degradation• Amine is corrosive at highconcentrations• Some amine loss due to low
vapour pressure of amine

G III-IV R&D Directions¾Advanced amines• Formulated mixtures, multiple amine groups¾Non-aqueous solvents• Ionic liquids¾Phase change solvents• Slurries, emulsions¾Modified process concepts• Intercooling, heat exchange integration in stripper, integration ofcompression, split flow

¾Novel process components• Membrane contactors, heat pumps¾ Robust solvents• Ammonia¾Biomimetic approaches• Enzymes for solvent process improvements

Solvent PCC Activities – G III Solvent systems

Macro-scaletesting

Micro-scaletesting

Molecularmodelling andstructure activity
relationships

Synthesis ofnovel amines

Pilot-scaletesting

Demonstration
plant

Process
engineering
andeconomics

Pilot plant flow diagram
CO2 lean fluegas

Product CO2

Water
Flue gas
washing

Direct contact
coolerFlue gas

Absorbent
regenerator
CO2
absorber

Pre cooler
Reboiler

Water

Absorbent
filterTransportable PCC Pilot Plant
Multiple transportable pilot plants• 1,000-5000 tpa• Pre-wash column for optional SOx / NOx
scrubbing• Dual 200-800 mm absorbers• Single stripper column

Relocatable for slip stream operation• Several power stations in program burning
black and brown coalModular construction• Plans for testing different packing types andnovel membrane contactors• Testing of alternative solvents (e.g. chiller
being added to test chilled ammonia as asolvent)

Sophisticated gas analysis• Providing data on solvent stability• Crucial information for environmental impact
assessments

Confirmed Pilot Plants- APP support- Munmorah Power Station- Black coal
- Ammonia based- No FGD/DeNox

Latrobe Valley Post
Combustion Project- APP support- Gaobeidian Power Station- Black coal
- Amine based- FGD/DeNox installed- ETIS support- Loy Yang Power Station- Lignite- Amine based- No FGD/DeNox

The PCC Team thanks you for your attention!
Energy Technology:
Paul Feron
Solvent development:
Moetaz Attalla
Graeme Puxty
Rob Rowland
Andrew Allport
Jewel Huang (ILs)
Process modelling:
Narendra DaveThong Do
Pilot Plants:
Aaron Cottrell
James McGregor
Scott Morgan
Doug Palfreyman
Russell Reynolds

Molecular & HealthTechnologies:
Mark Bown
Mohammed Chowdhury
Qi Yang
Minerals
Shi SuRamesh Thiruvenkatachari
Entomology:
Victoria Haritos
Greg Dojchinov

Marcel Maeder
Robert Burns
Nichola McCann

Gary Rochelle

Konrad Hungerbuhler
Bobby Neuhold
Levente Simon

Day 2 Tuesday 16 October 2007
Session 8: FBC/ USC/ IGCC/ CCS

Speech 2 PR China
Two-stage Dry-fed Entrained Flow Coal Gasifier

Mr. Xu Shisen
Chief Engineer
Thermal Power Research Institute (TPRI)PR China

TPRI

A Two-stages Pressurized Entrained
Flow Gasification with Dry Feed
Dr. Xu Shisen
Thermal Power Research InstituteOct. 2007

Xi’an

TPRI

CONTENTS•The Conception of the Two-stages
Entrained Flow Gasification with Dry Feed•

R&D on the Two-stages Entrained Flow
Gasification with Dry Feed•

The Demonstration of TPRI’s Gasification
Process

TPRI

Gasification

Fixed Bed

Lurgi
BGL
U.G.I.
Slurry feed

GE-Texaco
E-Gas
多喷嘴

Entrained Flow

Dry feed

Fluidized Bed

HTW
KRW
U-gas
Transport

Shell
Prenflo
GSP
MHI
TPRI

TPRI

ENTRAINED FLOW GASIFIER• It has high output, high efficiency and high carbon
conversion efficiency than that of moving bed andfluidized bed.

• It has high availability verified by the large scalecommercial gasifier.

• Main existing entrained flow gasifiers are:with slurry feed: Texaco, E-Gas, …
with dry feed: Shell, Prenflo, GSP,…

TPRI

IGCC AND ENTRAINED FLOW GASIFIER• Tampa 250MW IGCC----2500t/d Texaco• Wabash River 260MW IGCC----2500t/d E-Gas• Buggenum 250MW IGCC----2000t/d Shell• Purterllano 300MW IGCC----2500~3000t/d
PrenfloTPRI

ENTRAINED FLOW GASIFIER WITH DRY
FEEDAdvantages:• High cold gas efficiency, high carbon conversion
efficiency, low oxygen consumption
Disadvantages:• For cooling and separating the molten slag in hot
syngas at gasifier outlet, half part of cold syngas
must be compressed to quench the hot syngas, that
results the added energy loss, high auxiliary power
consumption, large scale syngas cooler and much
more cost.

TPRI

A TWO-STAGES GASIFIER WITH DRY FEED•Two stages reaction•Mult-burners•Water wall
•Molten slag
•No cold syngas quench•Low auxiliary power
consumption•Small syngas cooler•High cold efficiency•Low oxygen consumption

TPRI

TPRI’sGasification

700kg/d,1996, funded by MOST and SPC

36 t/d (10MWth )Funded by National“863” Program
2005

1000t/d，2000t/d, 2009

TPRI

TPRI

The change rate of second stage coal supply ratio
to cold gas efficiency

TPRI

The change rate of second stage coal supply ratio
to syngas temperature

TPRI

TPRI

TPRI

TPRI

TPRI

TPRI

TEST RIG• Capacity : 700kg/d• Pressure: 0~4.0MPa• Temperature: 1300~1600℃• It was built funded by State Power Corporationof China in 1998
• Research on pressured entrained flow
gasification

TPRI

TEST RESULTS• Pressure：3.0MPa• First stage coal flow rate：16kg/h；• First stage oxygen consumption：0.55Nm3/kg• First stage temperature：1360~1400℃• Second stage coal flow rate：4kg/h；• Second stage oxygen consumption：0Nm3/kg• Second stage temperature: 1100~1150℃

TPRI

TEST RESULTS• Syngas composition：
CO ：51.3%
H2：35.1%
CO2 ：6.3 %CH4 ：1.2 %N2：6.2%• Carbon conversion rate：95.9%• Oxygen consumption：294Nm3/1000Nm3 (CO+H2）• Cold gas efficiency：79.9%• Outlet temperature: 1000~1050 ℃

Pilot Scale Facility for
TPRI’s Gasification•Cold efficiency >83%
•Carbon conversion>98%•Oxygen consumption<320Nm3 /1000(CO+H2)•Temperature:
1300~1400℃•Pressure: 3.0～4.0MPa•Funded by MOST

TPRI
TPRI

TPRI

Control Center

TPRI
DCS of TPRI’s Gasifier

TPRI

PILOT SCALE TEST FACILITY• Capacity: 36-40t/d• Pressure: 3.0MPa• Temperature: 1400~1600℃• Funded by MOST and SPC• To be built in 2004
• Finished the tests of 13 Chinese coals

TPRI

Test Coals
Huangling

Jincheng
anthracite

12.5

8.2

6.8

4.86

7.52

1.21

1.34

9.92

10.68

17.24

22.15

13.76

44.95

36.09

38.10

35.17

8.88

55.05

63.91

61.90

%

47.43

66.71

55.16

58.03

72.39

Mad

%

3.13

4.09

3.57

3.58

2.63

收到基氮

Aar

%

0.55

0.78

0.57

0.83

1.00

收到基氧

Vdaf

%

12.25

11.97

10.42

6.66

3.08

全硫

FCdaf

%

0.22

0.87

0.54

收到基低位发热量

Qnet,ar

MJ/kg

18.80

26.57

21.80

收到基高位发热量

Qgr,ar

MJ/kg

17.55

25.61

20.78

变形温度

DT

℃

1140

1150

1300

1400

1390

软化温度

ST

℃

1160

1190

1370

1470

>1500

流动温度

FT

℃

1190

1250

1410

>1500

>1500

项目

符号

单位

ligniteShenmuHuating

全水分

Mt

%

26.5

4.9

空气干燥基水分

Mad

%

6.08

收到基灰分

Aar

%

干燥无灰基挥发分

Vdaf%

干燥无灰基固定碳

FCdaf

%

收到基碳

Mt

收到基氢

58.03

0.55
23.46
22.53

91.12

0.34
27.73
27.03

TPRI

Test Results
coals

Huangling

Jincheng
anthracite

62.79

60.36

59.93

29.36

28.46

26.98

25.78

0.05

0.26

0.17

0.04

0.02

CO2（%）

3.59

2.76

3.41

7.39

9.18

H2S+COS（%）

0.11

0.37

0.25

0.24

0.14

N2（%）

6.51

4.87

4.92

4.99

4.95

ligniteShenmuHuating

CO（%）

61.9

62.38

H2（%）

27.84

CH4（%）TPRI

Test Results• Carbon conversion rate：98.9%• Oxygen consumption: 298.6Nm3/1000Nm3（CO+H2）• Specific coal consumption ：518.2kg/1000Nm3(CO+H2)• Cold gas efficiency ：83.2%• CO+H2: 91.74%。

TPRI

Test Results
Gas components

Huating

ShenmuFirst stage

Two stageFirst stages

Two stages

CO（%）

62.38

60.63

62.79

60.50

H2（%）

29.38

32.64

28.46

31.93

CH4（%）

0.26

0.72

0.17

0.77

CO2（%）

2.76

1.07

3.41

2.81

H2S+COS（%）

0.37

0.35

0.25

0.25

N2（%）

4.85

4.59

4.92

3.74

TPRI
TPRI

Shenmu Coal Slag

Lignite Slag

Huangling Coal Slag

Jincheng Coal Slag

Entrained Flow Gasification

TPRI

TPRI
Comparison with the Existing Gasifier
A(Slurry Feed)

B(Dry Feed)

TPRI

Cold syngas eff.，%

70~75

78~81

83

（CO+H2），%

74~80

87~90

90~93

Carbon conversion，%

96

98

98~99

Thermal eff.，%

80~85

90

90~95

O2 consumption，
Nm3/1000Nm3(CO+H2)

380~410350≤310

Auxiliary power, %

85

100

80

Coals flexibility ，%

70

95

100

Burners life

3 months2y

2y

Inner shirt life, y

1

20

20

Start time, hr

26

2

2

Cost , ％

70

100

60～70

TPRI

TPRI’s Gasification Process with Syngas Cooler

TPRI

2000t/d TPRI’s Gasifier for 250MW IGCC
•
•
•
•
•
•
•
•
•
•
•

Huaneng Tianjin 250MW IGCC Demonstration Project of CHNG
With syngas cooler
Capacity: 2000t/d
Pressure: 3.0~3.5MPa
Temperature: 1400~1500℃
Syngas flow rate: 165000Nm3/h
O2 consumption：310 Nm3O2/1000Nm3（CO+H2）
Cold syngas eff.：83%
CO+H2：91%
Net power: 250MW
Start to operate in 2009

TPRI

T

TPRI’s Gasifier
with Syngas Cooler

TPRI
TPRI’s Gasification Process with Quenching煤粉来自磨煤
氮气来自空分
蒸汽

粗
煤
气

除氧水

汽包

煤粉输送

水泵
排污

激冷水

出气化炉水冷壁

煤气

水

气化炉

蒸汽

激冷罐

水泵

净煤气

文
氏
管
洗
涤
器

水
洗涤塔

进气化炉水冷壁氧气来自空分

排污
渣

排污

TPRI

1000t/d TPRI’s Gasifier for Chemical Project• 300kt/a Methanol Demonstration Project of Shilin Chemical
Ltd.
• With quenching• Capacity: 1000t/d• Pressure: 4.0MPa• Temperature: 1400℃• Syngas flow rate: 82000Nm3/h• O2 consumption：310 Nm3O2/1000Nm3（CO+H2）• Cold syngas eff.：82%• CO+H2：90%• Production: 250kt/a Methanol• Start to operate in 2009TPRI

TPRI’s Gasifier
with QuenchingThank you for your attention.

xushisen@tpri.com.cn
www.tpri.com.cn

Day 2 Tuesday 16 October 2007
Session 8: FBC/ USC/ IGCC/ CCS

Speech 3 Japan
Fluidized Bed Combustion Power Plant Technology
by Low-Grade Coal

Mr. Yoshiteru Nishie
Advisor to Director (China IPP Business)
International Power Business Department
Electric Power Development Co., Ltd.(JPOWER)Japan

Yoshiteru NISHIE
出生日期：1955.6.4
学

历：Waseda大学,科学工程系,电机工程专业资历：电机与电子工程师电气设备总工程师 (一级)能量消耗监控工程师

工作经历:
1981-1983

EPDC公司(现在的日本电源开发公司J-POWER) Takahara第三建筑办公室

1983-1985

EPDC公司(现在的日本电源开发公司J-POWER) 热能企划部

1985-1989

EPDCI公司(现在的日本产业活性化中心JPEC)马来群岛KL办公室(PKPS2)主任

1989-1993

EPDC公司(现在的日本电源开发公司J-POWER) 热能企划办公室副主任

1993-1995

EPDC公司(现在的日本电源开发公司J-POWER)中国Qingdao DeSOx实证办公室,副主任

1995-1997

日本产业活性化中心JPEC热能企划部,海外采购NTD副主任

1997-2002

日本电源开发公司J-POWER,国际商务部, IPP办公室 负责人

2002-2003

日本电源开发公司J-POWER,国际商务部，IPP办公室主任

2003-2005

日本电源开发公司J-POWER,国际商务部，IPP第四小组负责人

2005-至今日本电源开发公司J-POWER,国际商务部，中国IPP事务主任顾问

2000-至今中国陕西（山西）Tianshi能源公司执行理事

1

Yoshiteru NISHIE
Born in 4th June 1955
Graduated

Waseda Univ., Science and Engineering Dept.,
Electrical Engineering

Qualification Professional Engineer (Electrical & Electronics)
Electrical Equipment Chief Engineer (1st Grade)
Energy Management Engineer
Career2000-Current Executive Director of Tianshi Power Conpany in Shanxi, China
2005-Current Advisor to Director,

China IPP Business, International Business Dept.,

IPP No. 4 Group, International Business Dept.,

J-Power

2003-2005

Leader,

2002-2003

Deputy Director,

1997-2002

Manager,

1995-1997

Deputy Director,

Thermal Power Design Dept (Oversea’s Procurement NTD) (current JPEC)

1993-1995

Deputy Director,

Qingdao DeSOx Demonstration Office in China

1989-1993

Deputy Manager,

Thermal Power Design Office

1985-1989

Manager,

IPP Office, International Business Dept.,

IPP Office, International Business Dept.,

KL Office in Malaysia (PKPS2)

J-Power
J-Power

J-Power

EPDC(current J-POWER)

EPDC(current J-POWER)EPDCI(current JPEC)

1983-1985

Thermal Power Design Dept.,EPDC(current J-POWER)

1981-1983

Takehara No. 3 Construction Office

EPDC(current J-POWER)

2

Fluidized Bed Combustion Power Plant
Technology Using Low Grade Coal
发电厂硫化床使用劣质煤燃烧的技术
Electric Power Development Company.,Ltd
日本电源开发有限公司(J-Power)Oct．2007
Yoshiteru Nishie
3

Content
内容 Feature of bubbling FBC(BFBC) technology
流化床（BFBC）燃烧沸腾工艺的特性 Technical merit of BFBC developed in Japan
BFBC技术水平在日本的发展 Economics advantage and market
经济利益和市场 Merit for environmental protection环境保护的价值
4

１．

Feature of bubbling FBC (BFBC) technology
流化床（BFBC）燃烧沸腾工艺的特性（１）BFBC can burn low heat value fuel
BFBC能够燃烧低热量燃料（２）Small scale power plants can be equipped with re-heating cycle 小型电厂可以配备再加热循环设备
Small scale power plants achieve high efficiency
小型电厂可实现高功效
Coal washery low grade coal
(480million ｔ at 2020 in China）
Waste of energy

Small Plant in China
115million kW

Pollutant generation by spontanious

Low efficiency

洗煤厂劣质煤的能源浪费Pollutant source

Environmental friendly high efficiency BFBC
(Sending end 370g/kWh-390g/kWh:
Target value)
BFBC能提高能效115百万kW的中国小型电厂

低能效污染来源Partial modification部分改良
Closed 关闭5

２． Technical merits of BFBC developed in Japan BFBC technology was developed for the modification of oil
fired power plant in Japan during the 1980ｔｈ and 1990ｔｈ

・ High combustion efficiency(98% over) by 2 stage combustion
・ High generating efficiency by adding a re-heating cycle atsizes of 50MW-100MW・ Low combustion temperature (860℃）contributes to low NOx
emission (Evaporator, Super-heater, Re-heater are embedded)
・ 90%De-Sox efficiency thanks to low combustion temperature
・ Even mid scale(300MW) power plants could be modified to
BFBC through the adoptions of a 2-layer stack bed
・ Modification cost is much lower than for replacement6２． 日本BFBC发展的技术价值
 日本石油火力发电厂80年代和90年代间BFBC技术发展调整状况・ 通过两个阶段实现高燃烧功效（高于98％）・ 50MW-100MW型发电厂可通过增加一个再加热循环来提高发电功效・ 低燃烧温度（860 ℃）可降低NOx释放（内含蒸发器/脱水器，
过热器，再热器）・ 90％低-Sox功效源于低燃烧温度・ 即使中型发电厂（300MW）也可通过采用2层烟囱床改良为BFBC
・ 改良费用大大低于置换费用7

(1) Examples of BFBC in Japan - case1(Wakamatsu demonstration plant Modified from 75MW boiler) Output 50MW Steam 156t/h Temp.595℃/595℃, Pressure Tb inlet 10MPa
 Combustion efficiency 98.1％ to 99.8％
 Boiler efficiency（HHV）88.6％ to 90.4％（abt.93％ on LHV ） TG efficiency TG
42.0％
 House load factor 10.7％
 Sending end efficiency 34.8％
 Coal consumption (@ 7000kcal/kg coal) 353g/kWh (Sending end)
Feature:・Adopt two-stage combustion (main bed cell and carbon burn up cell)・Add re-heater
・Embed evaporator, super-heater and re-heater・Adopt a proper combustion temperature for de-sulfurization
・Achieve low NOx emission through low combustion temperature・Show a results record of up to 300MW by the stack layer (2-layer)
8(1) 日本BFBC的案例- case1(若松实验厂 75MW 锅炉的改良案例）
 产量 50MW
 蒸汽156t/h，
温度595℃/595℃,
压力 Tb inlet 10MPa 燃烧功效 98.1％ to 99.8％
 锅炉功效（HHV）88.6％ to 90.4％（abt.93％ on LHV ） TG功效
42.0％
 装载系数10.7％
 送电端功效 34.8％
 煤消耗量(@ 7000kcal/kg coal) 353g/kWh (Sending end)
特性:・采用两阶段燃烧 (main bed cell and carbon burn up cell)・增加再热器・插入蒸发器/脱水器，过热器和再热器・为脱硫采用合适的燃烧温度・通过低燃烧温度达到低NOx 排放・采用2层烟囱床将产量提升至300MW
910(2) BFBC modification Idea 改良方案
Pulverizedcoal fired boiler 煤粉锅炉
既設微粉炭ボイラ

改造案1
若松方式
Plan1
Wakamatsu
Plan
ベット面積に余裕有りSpacevelocity1.5ｍ/ｓ
空塔速度 1.5m/s
2段ベット方式

ボイラ断面積58.6m2
7.6mx7.6m

接合部
Conjunction

Stacktype(2Layers)

上部
ベット
FBC改造部

柱中心間 9mx15m

ボトム灰抜き出し装置

参考例

床面積上下段で130m2
下段
90m2
上段
40m2

若松50MW2段ベッド方式
床面積
下段
60m2
上段
40m2
平均空塔速度
1.72m/s
炉床負荷1.2百万kcal/m2

Plan2
改造案２

Standardization
ベット面積に余裕無し

At 50MW and 100MW
1段ベット方式

Lunch-Box type
接合部
Conjunction

FBC改造部
ボトム灰抜き出し装置
床面積下段で105.3m2

11

(3) Examples of BFBC in Japan – case 2
日本BFBC的案例2（Takehara第二石油火电厂350MW的改良）（Modified from Takehara N0.2 OIL fired plant 350MW）
Under operation since 1995
300 MW operating record (Largest in the world)
Boiler efficiency 93%(LHV)
Generating efficiency 38.5%(LHV)1995年以来的操作实况
300 MW 运行记录（全球最大）锅炉功效93％（ LHV）
产生功效38.5％ （ LHV）

12

3． Economical advantage and market 经济利益和市场
Small power plants with total output 115 million kW or more will be closed.
产量115百万KW以上的小型发电厂将被关闭。
10% of shut down plants could count for more than 10 million kW.
其中产量超过10百万kW的发电厂将占10％。
Modifying these 10 million kW power plant to BFBC plant using low grade coalwaste of 100 million ton per year is one of the clean coal technology .
将每年浪费100百万吨劣质煤的10百万kW电厂改良成BFBC是清洁煤技术之一。

This could applied to 100MW-300MW scale power plant.
BFBC也适用于100MW-300MW规模电厂
Target modification cost 改良目标成本
Cost pay back:within 5 years
Ratio to replacement cost: abt. 50％

成本在5年内收回
置换成本比率大概 50％
13４. Environmental protection Feature
环保特性（１）Circulating economy by using low grade coal
使用劣质煤产生循环效益（２）CO２emission decrease by high generating efficiency
CO2: Cutting 70,000t/year for 50 MW facility产生高功效减少 CO２排放，50mw电厂每年减少70,000t 排放（３）Low NOx emission at low temperature (860℃）
NOx: Half of expected emission (250mg/Nm3）<PCF
低温度的低NOx 排放，NOx排放量是预期的一半（４）High de-sulfurization by utilizing the de-sulfurizer in the ash
在灰中利用脱硫剂高效脱硫
SO2: 2500kcal/kg、S：2.5％、98％De-SOx by 2nd stage De-SOx
under 300mg/Nm3＜400mg/Nm3（Chinese Regulation）（５）Dust: Even ash content 60%, dust collecting efficiency 99.98%
灰尘：即使含灰量达到60％，灰尘收集功效高达99.98％（６）Complete ash utilization（cement, brick, block）
完成灰尘利用（水泥、砖、石块）

14

Ｅｎｖｉｒｏｎｍｅｎｔａｌ Ｐｅｒｆｏｒｍａｎｃｅ
环境效益

98%
99.98%DeSOx
Dust Collecting
Low Nox Emission

ESP+Bag Filter

BFBC
８６０℃
85％
DeSOｘ

2nd
FGD
90%

To cement factory

DeSOx

Water

Ash
cooler

Ca（OH）２
SlurryBlock Factory

15

Day 2 Tuesday 16 October 2007
Session 8: FBC/ USC/ IGCC/ CCS

Speech 4 PR China
Development and Status of Ultra Supercritical Power Generation
Technology in China

Mr. Zhu Baotin
Chief Scientist
Thermal Power Research Institute (TPRI)PR China

TPRI

中国超超临界发电技术的发展和现状The USC Technology in China
朱宝田 首席研究员ZHU Baotian Chief Scientist
西安热工研究院
Xi’an Thermal Power Research Institute2007-10-23

2007年 10月
October, 2007

1

1


前言// Foreword

TPRI

2006 年 底 ， 中 国 发 电 装 机 容 量 622GW ， 年 发 电 量
2834.4TWh，是世界第二大电力生产国家 全国装机容量中火电占77.83%，发电量中火电占83.00%
 发电用煤占煤炭消费的53.5%
 By the end of 2006, with the installed capacity of 622GW
and the generating capacity of 2834.4TWh. China has
become the second largest electricity-producing country
in the world.
 The installed capacity of thermal power accounted for
77.83%, the thermal power generating accounted for
83.00% in the year Coal consumption for power generation accounted for
53.5% of consumption
2007-10-23
2

水电

火电

核电

总装机容
量GW

GW

%

GW

%

GW

%

1995

217.224

52.18424.02

162.940

75.01

2.100

0.97

1996

236.54255.57823.50

178.864

75.62

2.100

0.89

1997

254.23859.73023.49

192.408

75.68

2.100

0.83

1998

277.289

65.06523.46

209.884

75.69

2.100

0.76

1999

298.768

72.971

24.42

223.434

74.79

2.100

0.70

2000

319.300

79.70024.96

237.500

74.22

2.100

0.66

2001

338.000

82.70024.47

252.800

74.79

2.100

0.62

2002

353.000

84.55023.95

264.200

74.84

3.700

1.05

2003

385.730

92.91024.09

286.150

74.18

6.190

1.60

2004

440.700

108.260

24.57

324.900

73.72

6.840

2.23

2005

508.000

117.000

23.03

384.000

75.59

6.840

1.35

128.57020.67

484.050

77.82

6.850

2007-10-23

2006

622.000

3

1.10

TWh

%

TWh

%

TWh

%

1995

全国总发电
量
TWh
1006.9

186.8

18.55

807.3

80.18

12.8

1.27

1996

1079.4

186.9

17.32

878.1

81.35

14.3

1.33

1997

1134.2

194.6

17.15

925.2

81.57

14.4

1.27

1998

1157.7

204.3

17.65

938.8

81.09

14.1

1.22

1999

1233.1

211.9

17.27

1004.7

81.48

14.8

1.20

2000

1368.8

244.3

17.84

1107.9

80.93

16.6

1.21

2001

1478.0

257.5

17.42

1202.0

81.33

17.4

1.18

2002

1640.0

271.0

16.52

1342.0

81.83

25.0

1.52

2003

1911.0

283.0

14.81

1579.6

82.66

47.0

2.46

2004

2187.0

328.0

15.00

1807.3

82.64

50.1

2.29

2005

2414.6

364.4

15.09

1985.7

82.24

53.1

2.20

416.7

14.70

2357.3

83.17

54.3

2007-10-23

2006

2834.4

水电

火电

核电

4

1.92

2006年全国发电装机构成

TPRI

2006年总装机: 6.22 亿千瓦
1.4%

0.4%
火电: 4.8405 亿千瓦
水电：1.2857亿千瓦

20.6%

核电:11座核电站870万千瓦
风电：80个风电场230万千瓦

77.6%

全国新投产装机容量10097万千 瓦
其中：火电9028万千瓦，占89.4%
水电971万千瓦，占9.6%
风电92万千瓦2007-10-23

5

TPRI
 2006 年 底 ， 47 台 超 临 界 、 超 超 临 界 机 组 投 运 ， 容 量
27680MW，占火电装机容量的5.7%
 到2020年装机容量将达到1200GW，火电机组仍将占总装机
容量的70%
 电力工业的发展有相当大的潜力和市场
 By the end of 2006, 47 SC&USC units has been put into
operation with 27680MW capacity, representing the share of
5.7% to the installed capacity of thermal power By the year of 2020, the total installed capacity of the nation
will reach 1200GW, and the share of thermal power willaccount for 70%
 The development of the power industry has a great potential
2007-10-23
6
and market

TPRI

发电装机容量增长及2010年规划
10

亿千瓦

9

总装机容量
火电
水电
核电

8
7

8.40

火电74.9%火电77.6%6

火电75.6%

5

4.84

4.42
3.38

4 3.19
3

5.08

6.29

6.22

2.38

3.91

3.57
2.53

2.66

3.84

2.90

3.29

2
1
年

0
2000

2001

2002

2003

2004

2005

2006

2010

•“十五”装机容量增长约60%•预计”十一五”增长约65%
2007-10-23•火电装机容量增长与总装机同比例增长7

2006年全国火电机组平均供电煤耗

TPRI

380
370

364.1

366

360

355.5

356.3

国电

华电

349.9
344.9

350
340
330
320
310

全国
2007-10-23

华能

大唐

中电投
8

全国近年火电机组平均供电煤耗及2020年目标

TPRI

470
450
g/kWh

430
410

392

390

370

370

366

355

350
320

330
310
2000

2005

2006

2010

2020

Year

•十五期间，火电供电煤耗下降了22克/千瓦时，平均每年下降4.4克/千瓦时•预计十一五期间，下降15克/千瓦时，平均每年下降3克/千瓦时•到2020年将达到320克/千瓦时的世界先进水平
2007-10-23

9

TPRI

超临界：22.115MPa，374.15℃
超超临界：没有明确的物理定义，仅表示技术发展的一个阶段
中国发电机组超超临界起始点：27MPa，或580℃
 SC ——22.115MPa，374.15℃
 USC——without a clear physical definition , but indicatinga stage of technology development
 The threshold of USC units in mainland China: 27MPa，or 580℃
2007-10-23

10

TPRI

2 中国超超临界电厂// USC power plant in China¾ 1992 年 ， 中 国 首 台 600MW 超 临 界 机 组 （ 参 数
24.2MPa/538℃/566℃）在华能石洞口二厂投入商业运行¾ 2004 年 ， 中 国 首 台 国 产 化 600MW 超 临 界 机 组 （ 参 数
24.2MPa/566℃/566℃）在华能沁北电厂投入商业运行¾

In 1992, the first 600MW SC unit ( parameter 24.2MPa/538℃/566℃)
was put into commercial operation in Huaneng Shidongkou No.2 power
plant in China¾

In 2004, the first domestic made 600MW SC unit (parameter
24.2MPa/566℃/566℃) was put into commercial operation in Huaneng
Qinbei power plant in China

2007-10-23

11

TPRI

沁北电厂超临界汽轮机（参数24.2MPa/566℃/566℃，保证热耗率7424kJ/kWh）

Qinbei power plant SC turbine
2007-10-23

12

TPRI
¾ 2007 年 8 月 ， 中 国 首 台 600MW 超 超 临 界 机 组 （ 参 数
25.0MPa/600℃/600℃，保证热耗率7424kJ/kWh）在华能营
口电厂投入商业运行¾ In August 2007, the first 600MW USC unit (parameter
25.0MPa/600℃/600℃) was put into commercial operationin Huaneng Yinkou power
plant, with the guaranteed
heat rate 7424kJ/kWh)2007-10-23

13

TPRI
¾
¾
¾
¾

¾

¾

2006 年 11 月 ， 中 国 首 台 1000MW 超 超 临 界 机 组 （ 参 数26.25MPa/600℃/600℃）在华能玉环电厂投入商业运行
2006年12月，华电邹县电厂1000MW超超临界机组（参数25.0MPa/600℃/600℃）投入商业运行至2007年9月，共4台1000MW超超临界机组投入商业运行
In November 2006, the first 1000MW USC unit (parameter
26.25MPa/600℃/600℃) in Huaneng Yuhuan power plant was put into
commercial operation in China
In December 2006, another 1000MW USC unit (parameter
25.0MPa/600℃/600℃) was put into operation in Huadian Zouxian
power plant in China
To September 2007, there are four 1000 MW USC units put into
commercial operation in China

2007-10-2314华能玉环1000MW超超临界机组

TPRI

 2003年11月签订主设备订货合同
 2004年6月开工建设 2006年11月28日投运 汽轮机——引进西门子技术，上汽成套供货 锅炉——引进三菱技术，哈锅成套供货

Huaneng Yuhuan 1000MW USC unit
 In November 2003, ordered main equipment
 In June 2004, started construction
 November 28 2006, put into service
 Turbine ——Siemens technology, supplied by STC
 Boiler——Mitsubishi technology, supplied by HBC
2007-10-23

15

TPRI

2007-10-23 Power Plant 1000MW USC Unit
Yuhuan16

玉环 Yuhuan 1000MW USC unit

TPRI 西安热工研究院对机组性能测试结果： 锅炉效率 93.88%
 汽轮机热耗率 7295.8 kJ/kWh 额定负荷发电煤耗 270.6 g/kWh、供电煤耗 283.2 g/kWh 机组热效率 45.4%
 NOX排放 270 mg/Nm3 、 SO2排放 17.6 mg/Nm3——各项技术性能指标均达到设计值，居国际先进水平Performance Test Results by TPRI : Boiler efficiency : 93.88%
 Turbine heat rate: 7295.8 kJ/kWh Rated load coal consumption for generate electricity: 270.6 g/kWh Coal consumption for power supply : 283.2 g/kWh Unit thermal efficiency: 45.4%
 NOX emission density 270 mg/Nm3 , SO2 emission density 17.6 mg/Nm3——The technical performances were reached the designed values, ranking
2007-10-23
17
the advanced international level

TPRI

邹县 Zouxian 1000MW USC unit

2007-10-23

保证热耗率 7354kJ/kWhGuaranteed heat rate 7354kJ/kWh

18

电厂
机号

容
量
M
W

蒸汽参数
MPa/℃/℃
/℃

投
运
日
期

玉环 #1

100
0

26.25/600/
600

200
6.11

玉环 #2

100
0

26.25/600/
600

邹县 #7

100
0

邹县 #8

转速
r/min

末级叶
片
吋/mm

哈锅（三菱）/上汽（西门子）

3000

4F45.3/11
50

200
6.12

哈锅（三菱）/上汽（西门子）

3000

4F45.3/11
50

25/600/600

200
6.12

东锅（BHK）/东
汽（日立）

3000

4F43/1092

100
025/600/600

2007东锅（BHK）/东
汽（日立）

3000

4F43/1092

100
02007-10-23

25/600/600

2008哈锅（三菱）/哈
汽（东芝）

3000

4F48/1219
19

泰州 #1

制造厂
（炉/机）

电厂
机号

电力
公司

容量
MW

原汀 #1
Haramachi

日本
Tohoku1000

松浦 #2
Matsuura

日本
EPDC

1000

三隅 #1
Misumi
原汀 #2
Haramachi

日本
Chugoku
日本
Tohoku

碧南 ＃4
Hekinann
碧南 ＃5
Hekinann

蒸汽参数
MPa/℃/℃/℃
25/566/593

投运
日期

制造厂
（炉/机）

转速
r/min

末级叶片
吋/mm

199707三菱/东芝

3000/1500

CC4F41/10
41

24.6/593/5
93199707

BHK/三菱3600/1800

CC4F46/11
68

1000

25/600/600

199806

三菱/三菱

3600/1800

CC4F46/11
68

1000

25/600/600

199807

BHK/日立3000/1500

CC4F41/10
41

日本
Chubu

1000

24.6/566/5
93200111

IHI/东芝3600

TC4F40/10
16

日本
Chubu

1000

24.6/566/5
93200211

IHI/东芝3600

TC4F40/10
16

橘湾 #1
日本
TachibanaEPDC
wan
橘湾 #2
日本
TachibanaEPDC
wan
常陆那珂
日本
#1Hitachin
Tokyo
aka
2007-10-23 德国
Niederause
m K
RWE

1050

25/600/610

200007

IHI/东芝3600/1800

CC4F48/12
191050

25/600/610

200107

BHK/三菱3600/1800

CC4F46/11
68

1000

24.5/600/6
00

200301

BHK/日立3000/1500

CC4F41/10
411025

26.5/580/6
00

2002

ALSTOM/ 西
门子

3000

20
6F45.3/11
50

TPRI
 目前国外共有10台1000MW超超临界机组运行（日本9台、德国
1台）
 玉环1000MW超超临界是单轴机组，压力比日本高，温度比德
国高，是当今国际上容量最大、参数最高、同比效率最高的
超超临界机组，其总体技术水平居国际前列 Up to now, about 10 1000MW USC units were units put into
operation in abroad (9 units in Japan, 1unit in Germany) The 1000MW USC unit in Yuhuan is single shaft unit, with
the inlet pressure higher than those in Japan and the inlet
temperature higher than that of Germany. It is the unit withthe largest capacity, the highest parameter, and the highest
efficiency at same condition in the world. And the overall
2007-10-23
21
technology stands at the forefront of international level2

超超临界发电技术的研发

¾
¾
¾
¾
¾
¾
¾

The R&D of USC power technology
国家发改委“九五” 《600MW超临界火电机组研制》
大型超临界汽轮机研制
大型超临界锅炉研制辅机设备研制超临界机组系统优化及提高运行性能的研究
超临界机组材料和铸锻件国产化超临界火电机组自控系统和关键仪表研制
超超临界机组预可行性研究

TPRI“The Ninth Five-Year” program of National Development and Reform Commission “600MW SC Power Unit Development”¾
R&D of large SC turbine¾
R&D of large SC boiler¾
R&D of Auxiliary equipment¾
System optimization and performance improvement of SC unit¾
Domestic SC Unit materials and castings¾
R&D of SC power unit control system and the key instrument22¾2007-10-23
USC units pre-feasibility

国家863计划《超超临界燃煤发电技术》


TPRI



中国华能集团和中电投集团牵头，三大动力集团、西安热
工院、华东电力设计院等共同完成研发工作依托工程——华能玉环1000MW超超临界工程

科研和工程项目相互促进
National “863 Program” “USC coal-fired power generation
technology"The research and development work was leaded by China Huaneng
Group and China Power Investment Corporation, and conducted by
the three major power generating equipment manufacturing groups,
Thermal Power Research Institute, and East China Electric Power
Design Institute
Huaneng Yuhuan 1000MW USC project was the Supportive project
Research and project promote each other2007-10-23

23

国家 863计划《超超临界燃煤发电技术》¾ 子课题1

TPRI

超超临界发电机组技术选型研究¾ 子课题2 超超临界锅炉关键技术研究¾ 子课题3 超超临界汽轮机关键技术研究¾ 子课题4 烟气净化技术研究¾ 子课题5超超临界机组电站设计与运行技术研究

National 863 Program “USC coal-fired power generation
technology" technology"¾

Subject 1 Research on technology selection of USC power unit¾

Subject 2 Research on USC boiler key technology¾

Subject 4 Research on flue gas purification technology¾2007-10-23
Subject 5 Research on design and operation of USC power plant

24

（1）
超超临界发电机组技术选型研究 再热次数—— 一次再热 参数—— （25MPa—28MPa）/600℃/600℃

TPRI

 超超临界对材料的要求
 容量—— 600MW，1000MW 锅炉主要结构形式
 汽轮机主要结构形式（1）Subject 1 Research on technology selection of USC unit
 Reheat number—— one reheat Parameter （25MPa—28MPa）/600℃/600℃
 Requirements for material of USC unit Capacity ——600MW，1000MW
 The main structure of boiler
 The main structure of turbine
2007-10-23
25

（2） 材料研究

TPRI

热强度性能高温烟气腐蚀性能
高温汽水氧化性能工艺性和焊接性能国外的应用经验(2) Materials Research
Properties of thermal strength
High temperature gas corrosion
High temperature oxidation of steam
Craft technology and welding PerformanceApplication experience in abroad

2007-10-23

26

（3）

超超临界锅炉关键技术TPRI

 传热与水动力特性研究
 1000MW超超临界锅炉总体设计集成技术
 1000MW超超临界锅炉设计——п型螺旋管圈锅炉、п型垂直管圈锅炉、
塔式螺旋管圈锅炉 耐热新钢种材料性能和应用研究 耐热钢管的加工、焊接及热处理工艺（3） Research on USC boiler key technology
 Research on heat transfer and hydrodynamic characteristics
 1000MW USC boiler design integration technology
 1000MW USC boiler design ——п-type spiral tube circle boiler, п- typevertical tube circle boiler, tower-type spiral tube circle boiler
 Research on material properties and application of the new heat-resistantsteel
2007-10-23
The processing, welding and heat treatment process of heat-resistant pipe
27

TPRI

2007-10-23

П布置垂直管圈锅炉п-type vertical tube circle boiler

28

2007-10-23

П布置螺旋管圈锅炉п-type spiral tube circle
boiler29

TPRI

2007-10-23

塔式布置螺旋管圈锅炉Tower-type spiral tube circle boiler

30

TPRI
（4） 超超临界汽轮机关键技术 1000MW超超临界汽轮机设计集成技术
 1000MW超超临界汽轮机可靠性研究
 1200mm末级叶片研发
 耐热钢的加工及热处理工艺（4） Research on USC turbine key technology
 1000MW USC turbine design integration technology
 1000MW USC turbine reliability
 The R&D of 1200mm last blades The processing and heat treatment process of heat-resistantsteel
2007-10-23

31

2007-10-23

32

TPRI
（5） 超超临界机组电站设计技术研究 1000MW 超超临界机组电站设计规范 主蒸汽管道、再热热段/冷段管道、给水管道材质的选择与设计 电站主要工艺系统 电站辅机选型配置（5） Design technology of USC power plant The power plant design specifications with 1000MW USC
unit
 The choice of materials and design of main steam pipeline,
hot reheat steam section / cold section of the pipeline, andfeedwater pipeline Power plant’s main processing system
2007-10-23
33
 Power plant’s auxiliary selection and configuration

TPRI（6） 超超临界机组运行技术研究变负荷运行和优化运行技术调峰运行方式
水汽化学运行与控制方式（6） Research on operation technology of USC
power unitVariable load operation and optimization ofoperation technology
Operation mode of duty loadChemical vapour operation and control mode
2007-10-23

34

TPRI

（7） 烟气净化技术研究

 大型燃煤电站烟气脱硝技术（SCR）的研发 超超临界燃煤发电烟气脱硝系统设计（7） Research on flue gas purification technology
 Research on flue gas denitrification technology(SCR) of large coal-fired power plant System design of flue gas denitrification for Ultrasupercritical coal-fired generation
2007-10-23

35

4


超超临界发电设备制造业
USC power generating equipment manufacturing

TPRI

2003年，中国引进国际上已有的先进和成熟的超超临界技术，消化吸收再创新，达到国产化的目标
¾
东方锅炉厂(日立技术)¾哈尔滨锅炉厂(三井巴布可科技术、三菱技术)¾
上海锅炉厂(阿尔斯通技术)¾
东方汽轮机厂(日立技术)¾哈尔滨汽轮机厂(三菱技术、东芝技术)¾
上海汽轮机厂(西门子技术)
In 2003, China introduced advanced and mature USC technology andstruggled to digest and innovate to achieve the domestic-made goal¾
Dongfang Boiler Co.Ltd. (Hitachi technology)¾
Harbin Boiler Works (Mitsui-Babcock and Mitsubishi technology)¾
Shanghai Boiler Co.Ltd. (Alstom technology)¾
Dongfang Turbine Co.Ltd. (Hitachi technology)¾
Harbin Turbine Co.Ltd. (Mitsubishi and Toshiba technology)
2007-10-23
36¾
Shanghai Turbine Co.Ltd. (Siemens technology)

TPRI东锅 1000MW超超临界锅炉
П型炉
前后墙对冲燃烧方式
内螺纹管螺旋管圈水冷壁
1000MW USC boiler made by Dongfang Boiler
Co.Ltd.
П-type boiler
Vis-a-vis flushes firing between the front and rearwallInner screw spiral tube circle waterwall
2007-10-2337哈锅 1000MW超超临界锅炉TPRI

 П型布置单炉膛 反向双切园燃烧方式
 低NOx分级送风燃烧系统
 内螺纹管垂直上升膜式水冷壁(入口装设节流孔圈) 1000MW USC boiler made by Harbin Boiler Co.Ltd.
 П-type arrangement single furnace
 Bi-tangential circle firing De-NOx combustion system with fractional air supply Inner screw vertically arising membrane water (installorifice laps in inlet)
 The starting system with boiler recirculation pump
2007-10-23

38

TPRI
 上锅 1000MW超超临界锅炉
 Π型布置/塔式布置 单炉膛双切圆/单切圆燃烧方式
 平衡通风 固态排渣
 螺旋管水冷壁/垂直管水冷壁
 1000MW USC boiler made by Shanghai Boiler Co.Ltd.
 Π-type arrangement /Tower-type arrangement
 Single-furance bi-tangential/ Single-tangential combustiontype Balanced draft Dry slagging coal dust
2007-10-23
39Spiral tube waterwall / Vertical tube waterwall

TPRI东汽 1000MW超超临界汽轮机单轴四缸四排汽43英寸（1092mm）末级叶片 1000MW USC turbine made by Dongfang Turbine Co.Ltd.
 Single shaft
 Four-cylinder four exhaust 43-inch (1092mm)
last blades
IP Tu r b in e

2007-10-23

40
H P Tu r b in e

TPRI哈汽 1000MW超超临界汽轮机单轴四缸四排汽48英寸(1219mm)末级叶片 1000MW USC turbine made by Harbin Turbine Co.Ltd.
 Single shaft
 Four-cylinder four exhaust 48-inch (1219mm) last blades

2007-10-2341 上汽 1000MW超超临界汽轮机

TPRI

 单轴
 四缸四排汽 圆筒型高压缸/补汽调节阀 1146mm末级叶片 1000MW USC turbine made by Shanghai Turbine Co.Ltd Single shaft
 Four-cylinder four exhaust Tube-type high pressure
cylinder / additional steam
control valve
1146mm last blades
2007-10-23

42

TPRI

5

超超临界发电在中国的发展前景
USC development prospects in mainland China超超临界发电已大容量和规模化商业运行是国际上，也是中国燃煤火电机组发展的主导方向
在材料工业发展的支持下,正朝着更高参数、更高效率的方
向发展





Up to now, USC technology has been used successfullycommercial operation in large capacity unit
USC technology is the dominant direction of developmentof coal-fired generating units in China and in the world
With material development, the tendency of USC
technology will be higher parameters and greater efficiency

2007-10-2343 中国超超临界发电机组的其它发展方向
 容量扩展：1200MW——1300MW

TPRI¾ 机组类型多样化： 1000MW超超临界抽汽供热机组
 1000MW超超临界空冷机组
 CFB超临界锅炉
 Other developments USC units in mainland China
Capacity expansion: 1200MW——1300MW¾ Unit types variety: 1000MW USC for extraction heating unit
 1000MW USC for dry-cooled unit
 CFB SC boiler
2007-10-23

44

TPRI

中国已形成完整的超超临界机组研发、设计、制造及超超临界电站设计、建设、运行基础
掌握了超超临界发电技术，达到国际先进水平 China has a complete basis of research, development,
design, and manufacturing of USC unit. And it also has abasis of the design, construction and operation of USC
power plant.
 USC power generation technology in mainland China
represents the international advanced level2007-10-23

45

TPRI






至2007年6月底，建设或在制中的超临界、超超临界机组600MW级超临界机组180多台
1000MW超超临界机组30台
660MW超超临界机组26台
600MW超超临界机组8台



By the end of June 2007, USC units which were underconstruction or manufacturing in mainland China include :600MW grade SC units —— about 180 units
1000MW USC——30 units
660MW USC——26 units
600MW USC——8 units






2007-10-23

46

1000MW USC机组（32台-2007.06）
电厂

台数

制造厂

电厂

台数

制造厂

玉环

4

哈锅/上汽

宁海

2

上锅/上汽

泰州

2

哈锅/哈汽

北疆

2

上锅/上汽

潮州

2

哈锅/哈汽

平海

2

上锅/上汽

邹县

2

东锅/东汽

外高桥

2

上锅/上汽

海门

2

东锅/东汽

漕泾

2

上锅/上汽

绥中

2

东锅/东汽

蒲圻

2

上锅/上汽

惠来

2

东锅/东汽

彭城

2

上锅/上汽

2007-10-23

北仑

2

东锅/上汽

2005.112005.122006.122007.

47

660MW USC机组（26台-2007.06）
电厂

台数

制造厂

芜湖

2

哈锅/东汽

吕四港

4

哈锅/哈汽

西塞山

2

哈锅/东汽

下关

2

哈锅/上汽

宁德

2

东锅/东汽

新昌

2

东锅/东汽

信阳

2

东锅/哈汽

望亭

2

上锅/上汽

常德

2

上锅/上汽

乐清

2

上锅/上汽

禹州

2

上锅/哈汽

2007-10-23

黄埔

投运时间

48

2

上锅/上汽

600MW USC机组（8台-2007.06）
电厂

台数

制造厂

投运时间
2007.08
2007.10

营口

2

哈锅/哈汽

阚山

2

哈锅/哈汽

河源

2

哈锅/哈汽

铁岭

2

哈锅/哈汽

2007-10-23

49






TPRI
到2010年，中国超超临界机组将占全世界超超临界机组的
半壁江山
预计到2020年，超临界和超超临界机组在中国新增火电市
场的份额可达70%(装机容量240GW——400台600MW机组
或240台1000MW机组)超临界及超超临界发电技术——在发电领域未来30年伴演
主要角色






By 2010, the USC units in China will account for half of USC worldwide
It is expected that SC and USC units will reach 70% of new thermal
power market in mainland China (240GW installed capacity ——600MW 400 units, or 1000MW 240 units) by the year of 2020
It can be seen that SC and USC technology for power generation – play
the main role in the next 30 years in China
2007-10-23

50

TPRI

谢 谢!
Thankszhubaotian@tpri.com.cn
www.tpri.com.cn
029-82102520
西安热工研究院 TPRI
2007-10-23

51

TPRI

朱宝田
 工学博士 西安热工研究院首席研究员
 从事发电厂设备和系统的研究开发工作
 享受国务院政府特殊津贴 国家科技部“十五”863项目首席科学家
 国家科技部“十一五”863计划专家 全国劳动模范

zhubaotian@tpri.com.cn
029-82102520
2007-10-23

52

Day 2 Tuesday 16 October 2007
Session 8: FBC/ USC/ IGCC/ CCS

Speech 5 Korea
Analysis of 3-TPD Coal Gasification System in Korea

Dr. Hyung Taek Kim
Professor
Division of Energy System
Ajou University
Korea

Status of IGCC R&D Program in Korea< Operation Experiences of 3 TPD Gasifier System
and Planning of 300 MW Demonstration Plant >October 2007
Hyung-Taek Kim, Ph.D.
Professor in Energy Engineering, Ajou University
Expert Advisor, Korea Energy Management Corporation

Contents
 Introduction
 Pilot-scale 3 TPD Gasification System
 Plant Description
 Results of Continuous Run
 Criteria for the Candidate Coal Selection National Program of Demonstration IGCC Plant
 Background Present Status SummaryIntroduction
Introduction

Why coal now?
 Remaining Ultimate Recoverable Fossil Fuel Resources
Oil

Natural Gas

Conventional

Unconventional

1.7×1012 toe

4.4×1012 toe

1.7×1012 toe

Coal

55×1012 toe

Source : Shell Coal Gasification Process, Chhoa, 2003

International Utilization Sector of Coal

Other
12% Industry

8%
Other
Industry
12%

16%
Residential 3%
3%Powergeneartion
69%

2002

Power
geneartion
79%

Residential
1%

1%

2030

 Amount of Coal Utilization in Power Generation is steadily increase.
 Requirement of Low-Pollution, High-Efficiency CCT.

Conceptual Process of IGCC

Coal

Gasifier System
Gasifier
Gasifier

SyngasPurification
SystemHeat
Heat
Exchanger
Exchanger

Slag
OxygenSteam

Combined Cycle
A S U

Air

S/T Power
Generation

G/T Power
Generation

Electricity

SulfurApplication Area of Gasification Technology

CO2 Reduction with Different Fuels in Power Plant

Comparison of Pollutant Emission
 IGCC Process emits minimal amounts of pollutant.
 IGCC recognized as future power plant option.

100

250

Particulate( mg/Nm3 )
40

P.C.

502

227

176

P.C. + FGD

150

200

40

Demkolec IGCC

15

63

1.5

Wabash IGCC

7

32

6.6

84 ( * )33

4SOx ( ppm ) NOx ( ppm )Emission standards
Boryung Power Plant

Vacuum Residue IGCC

Pilot-scale
Pilot-scale
33 TPDTPD Gasification
Gasification System
System3 TPD Gasification System

Process & Flow Diagram of Gasification System

Initial Operation Condition of Gasifier

Operation Data of Gasification (Baiduri, 26 atm.)

Gasification of Baiduri (Gas Composition)

Gasification of Baiduri (Efficiency)

Carbon Conversion (Baiduri, 26 atm.)- Fly ash 3(Scrubber, dry) : 0.04kg(C: 34.34%)- Carbon in Scrubber : 0.0137kg (C : 0.003%)- P.C.(as-feed) : 585 kg(M : 3.58%)- P.C.(dry) : 564kg (C : 69.93%)- Input Carbon : 394kg (C : 100%)- Fly ash 2(Cyclone 2, dry) : 0.49kg(C: 28.23%)- Carbon in Cyclone 2 : 0.138kg (C : 0.0035%)- Fly ash 1(Cyclone 1, dry) : 0.23kg(C: 11.15%)- Carbon in Cyclone 1 : 0.026kg (C : 0.007%)

CarbonCarbonConversion
Conversion::99.95%
99.95%- Slag : 11.0 kg (C : 0.31%)- Carbon in Slag : 0.034 kg (C : 0.009%)

Operation of 4 Day PeriodCarbon Conversion, Cold Gas efficiency

Elemental Analysis of Coals Used
C
80
70

71.45

H

O

70.61 72.96 67.08

N

S

Ash

68.08 70.77

74.15

63.04

6054.4
50
40
30
20
10
0

rli/kg)h g)lli /kg) us /kg) on/kg)
o
g
o
g)
g)
g)
u
kl/ykg)
r
g
k
k
k
e
c
n
/
/
/
/k
l
l
l
l
l
l
a
s
r
t
d
a
l
a
b
c
a
a
a
a
a
a
i kc y p kc
vkca
y6kc
rr4kca ato08kc ide70kc A d48kc Bai67k
s
a
o
0
4
u
r
5
8
0
3
U (53
K (56
C(60
i(s7139
7
D (66
C(661
(6
D(65
(6
n
De

Ash Fusion Temperature (Reducing State)

Ash Fusion temperature (oC,)

1800
1700
1600
1500
1400
1300
1200
1100
1000
U

el
b
si

li
C

us
r
yp

Dr

on
t
ay

r
Cu

r

h
g
a

Da

ng
o
t

de
i
K

co

ro
a
Ad

ri
y
k
u
s
id
v
a
o
B
s
ni
e
D

Classification of Candidate Coal
3.0
Denisovsky(R)Curragh(A)Kleinkopje (S)Black Water (A)2.5

Zone D

Fuel Ratio (FC/VM)

South Black Water (A)Blair Athol (A)

대동CH)

2.0

Moura (A)Ermelo(S)Zone B

Datong (CH)
Warkworth (A)Drayton (A)1.5

Ulan (A)
Lemington (A)신목(CH)

Zone A

Wambo (A)Coal Valley (CA)Pittsburgh (U)Drayton(A)Plateau (U)Zone C

Illinois #5 (U)Cyprus(A)Obed (CA)Adaro(IN)

Baiduri(IN)1.0

Kideco(IN)A

Usibelli(U): Australia

태평양 (J)CA : Canada
CH : China

0.5

IN : Indonesia
J: JapanR: Russia

S: South Africa

U

: USA

: 3톤/일급 가스화기 적용 탄종(한국/고등기술연구원): 2톤/일급 가스화기 적용 탄종(일본)

0.0
1100

1200

1300

1400

Ash Fusion Temp.

1500

1600

Characteristics of Zone A Coal
Evaluation for Gasifier
Coal

Slagging
Potential

Char
Formation

Gas
Composition

CarbonConversion

Cold Gas
Efficiency

Usibelli (USA)

easy

small

CO : 60~65
H2 : 20~28

90~10060~70

Cyprus (USA)

easy

small

CO : 55~60
H2 : 30~35

85~10060~75

Kideco(Indonesia)

easy

small

CO : 50~70
H2 : 20~28

80~10060~75

Baiduri(Indonesia)

easy

small

CO : 60~67
H2 : 22~33

83~100

60~70

Korea
(3T/D)

ref.

Usibellicausingfoulingproblems inheat
exchanger

Flyslag Fouling in the Exit section of Gasifier

Coal : Alaska Usibelli
Operating Pressure : 15 kg/cm2

Characteristics of Zone B Coal
Evaluation for Gasifier
Coal

Korea
(3T/D)

Datong (China)

Slagging
Potential

Char
Formation

Gas
Composition

CarbonConversion

Cold Gas
Efficiency

easy

relatively
small

CO : 60~65
H2 : 20~30

90~100

60~70

ref.

Characteristics of Zone C Coal
Evaluation for Gasifier

Coal

Korea
(3T/D)

Drayton(Australia)

ref.
Slagging
Potential

Char
Formation

Gas
Composition

CarbonConversion

Cold Gas
Efficiency

difficulty

relatively
high

CO : 60~70
H2 : 30~35

80~100

63~70

need
flux

Characteristics of Zone D Coal
Evaluation for Gasifier

Coal

Slagging
Potential

Curragh (Austraiia)

Char
Formation

Gas
Composition

CarbonConversion

Cold Gas
Efficiency

high

CO : 60~65
H2 : 18~22

80~90

42~58

high

CO : 55~60
H2 : 20~25

65~80

40~60

Difficult,
Unburnedchar
problemKorea(3T/D)
Denisovsky (Russia)

ref.

inadequate
coal forgasification
Need charrecycleCharacteristics of Gasifier Operation
Gasification

Ash

Char
Production

Compatibility

Coal

Zone

Ash (%)

Usibelli (U)

A

10.86

Cyprus (U)

A

3.96

Drayton (A)

C

10.99

Curragh (A)

D

17.37

Kideco (IN)

A

1.68

O

Adaro (IN)

A

4.12

O

Baiduri (IN)

A

5.32

O

Denisovsky (R)

D

13.24

Datong (C)

B

8.09

Slagging

O

O

Good

ProblemCommercial
Commercial IGCC
IGCC Power
Power
Plant
Plant

Background Korean Government’s Plan to increase NRE utilization
 By the year 2012, 7% of total power generation will be covered by NRE Power sector planning to construct # 1 IGCC power plant Construction of 300MW CCT will be completed by 2012 Strategy of acquiring the design and demonstration of IGCC plant License agreement with Gasifier Vender Detailed Design by Korean Engineering Company
 Manufacturing most of the equipment in Korea

Objective
Final objective
 Design & Demonstration of 300MW class IGCC Plant
 Maximize the Korean Participation

Target Thermal efficiency: over 42% (HHV, Net) CO2 : 10% reduction,
 NOx: below 20 ppm, SOx: below 15ppm
 Domestic portion of Design: over 90%
 Korean Manufacturing of Equipment : over 90%

Schedule of the Projectschedule
3phase ’12.12~’15.12(3yr)2phase ’09.12~’12.12(3yr) Demon. Operation
1phase ’06.12~’09.12(3yr) Construction of IGCC
Design of IGCC
- Operation of 300MW- Construction of
300MW IGCC Plant- Gasifier vendor contract- Design of IGCC Demo Plant-Development of
Operation Technology
of Demo Plant

Demo. Plant-Renovation of Design
through Operation
Experience, R&D

Research & Development & Demo. Program Project 1 : Develop Design Capability of Gasifier(Doosan, KAIST, Yonsei University)y Acquisition of PDP through Liscence Agreement with Gasifier Vendery PEP of Gasification/Purification Process is Digested by Doosany Manufacturing of Gasification/Purification Plant is Managed Domestically※ PDP (Process Design Package)※ PEP (Preliminary Engineering Package)
Plant Engineering

Liscence
Agreement(Foreign)

PDP
PDP

ASU
G/T
G/T
Combined
Combined
Cycle
Cycle

Gasifier
Development of
Unit Process(Domestic)

Domestic Plant
Design Technology

Purification

IGCC Plant Design

Research & Development & Demo. Program□ Project 2 : Design & Construction of IGCC Plant(Western Power, KOPEC)• Design of Entire IGCC Plant except Gasifier and ASU• Managing Engineering Procedure (EPC)• Evaluation of Environmental Effect{ Construction Roadmap
1st Stage (3 year)
Liscence BasicFor
Agreement Design

가스화
공정사
선정

300MW IGCC Plant
Engineering플랜트 종합설계
/ 환경영향 평가

3rd Stage (2 year)

2nd Stage (3 year)

실시
계획
승인

건설
기본
계획

발주
계약
부지
정지

300MW IGCC Plant
Procurements & Construction

Pre-Operation

Demo Operation/설비개선기자재 제작/구매
300MW 실증플랜트 건설시운전시뮬레이터 개발 및시운전요원 교육준공검사플랜트 실증운전설비 안정화 및 개선

Research & Development & Demo. Program□ Project 3 : Operation & Maintenance of Demo Plant- KEPRI, Power Co, KEPCO, SNU, Inha, Korea, Kunsan{ Management Technology of Demo Plant{ Develop IGCC Plant Manpower{ Availability: Increase 78~82% Æ 92% [PC Plant]• Optimozation of Gas Turbine Combustion• Develop Real-time Operation Watching System• Develop Operation Simulator, Train Operator산소분리설비
14%
가스화기
23%

가스터빈
복합발전
56%

가스정제
7%

Operating Malfunction

Watching Program

Simulator

Research & Development & Demo. Program□ Project : Pilot Test-Bed and Development of Unit Process- KEPRI, Power Co., KEPCO, Doosan, IAE, KIER, Ajou, Hongik, Suwon{ Develop Gasifier Parts with Pilot Gasifier{ Pilot Test-Bed [30TPD] Construction{ Coal Selection, Preliminary Operation, Trouble shooting, Reliability Test
{ Develop Desulfurization & Dedusting Process

Pilot Gasifier (KEPRI, IAE, KIER)

IGCC HT Filter

Strategy
 Government supported National Project
 Government & KEPCO• Project Management and financial support
 Doosan Heavy Industry / KOPEC• 300MW IGCC Design, manufacture and construction
 Western Power CO• Plant site, construction and operation
 KEPRI• Management & Technical support for whole project License Agreement with Gasifier Vendor
 candidate vendors• Shell, GE Energy, ConocoPhillips, MHI PDP introduced from the vendor, PEP from Engineering Company
 Plant Design, manufacturing and construction of IGCC should be
conducted by Doosan and KOPEC

SUMMARY The position of coal as power generation fuel source
and coal-utilizing CCT technology is explained.
 Because of IGCC’s high efficiency and clean
environment characteristics, IGCC is most advanced coalutilization technology in the future power generation
market.
 Baseline methodology for selecting candidate coal for
gasification is established with coal characteristics suchas fuel ratio and ash fusion behavior
 Explain the Korean national project of for
design/construction/operation of 300 MW demonstration
IGCC plant

Members of Energy Process Laboratory(Accredited Best Lab in NRE Area by MOCIE)
Professor
Hyung-Taek, Kim

Post Doc. Researcher

Hong yue, Wang
Master candidates

Joon Soo, LeeChang

Su Young, Jung

Ph. D candidates

Young Shin, Jeon
Shim

Li Hua, Xu

Hyun Min,

Young Hoon, Kim

Hueon, Nam gung

Na Hyung

Day 2 Tuesday 16 October 2007
Session 8: FBC/ USC/ IGCC/ CCS

Speech 6 Canada
Carbon Capture and Geological Storage Projects in APEC

Dr. Frank Mourits
Senior Science and Technology Advisor
Office of Energy R&D
Natural Resources Canada (NRCa)
CanadaCarbon Capture and Geological Storage
Activities in APEC
Clean Fossil Energy Seminar
Asia-Pacific Economic Cooperation (APEC)
Xi’an, P.R. of China
15-17 October 2007

Dr. Frank Mourits
APEC Expert Group on Clean Fossil Energy
Natural Resources Canada
Ottawa, Ontario, Canada
1Presentation Overview• Introduction• Overview and Results of Phases I – III• Weyburn-Midale Example• Next Steps

Overview of Carbon Capture and Storage Activities in APEC
2

What is APEC?
Asia Pacific Economic
Cooperation (APEC):• 21 member economies• 41% of the world's population• 61% of world gross domestic
product (GDP)• 49% of world trade
APEC 2004 Energy Data:*• 60% of the world's primary energy
consumption• 58% of global greenhouse gas
emissions• 21 Gt CO2-eq, increasing to 48 Gt
CO2-eq in 2050
*ABARE September 2007

Overview of Carbon Capture and Storage Activities in APEC
3

What is CCS (Carbon Dioxide Capture and Storage)?

CO2

CO2 plumeCO2 dissolved information water
Overview of Carbon Capture and Storage Activities in APEC
4

IPCC Special Report on CCS (2005)

Different mix of stabilization and mitigation options in each economy:• Conservation and increased efficiency• Switching to lower-carbon fuels (e.g. coal to gas)
¾ Carbon dioxide capture and storage (CCS) – best potential forlarge-scale reductions in near-term• Renewable energy (wind, solar, biofuels)• Nuclear energy• Enhanced natural carbon sinks (reforestation, modified tillage)
Overview of Carbon Capture and Storage Activities in APEC
5APEC CCS Project Overview
 In 2002, the APEC Expert Group on Clean Fossil Energy(EGCFE) and the Energy Working Group (EWG) launched a
CCS initiative with the overarching goal to:• assist developing APEC members to successfully identify,
evaluate and develop prime CO2 capture and geological storage
projects in their economies

 Objectives of multi-year program:• explore the potential for CO2 capture and geological storage
technologies in the APEC region• raise awareness of and build capacity in CO2 capture andgeological storage in APEC

 Status:• three project phases completed to date; a fourth phase has justbeen approved by APEC
Overview of Carbon Capture and Storage Activities in APEC
6

Project Partners
The Delphi Group(Canada)The Alberta ResearchCouncil (ARC)The Cooperative ResearchCentre for Greenhouse Gas
Technologies (CO2CRC)

IEA Greenhouse Gas R&D
Programme (IEA GHG)

Alberta Energy and Utilities Board

Overview of Carbon Capture and Storage Activities in APEC
7

Project Funders APEC Australian Government
 US Government (DOE – NETL) Canadian Government (NRCan) IEA – GHG Programme

Overview of Carbon Capture and Storage Activities in APEC
8

Phase I - Assessment of Geological Storage Potential of
Carbon Dioxide in the APEC RegionPhase I timeline: March 2004 – June 2005



Execution: Australian teamObjective:• Assess the potential for geological storage of CO2 in
Asia Pacific Rim, exclusive of Japan and Russia

Results:• Inventory of CO2 emissions in study region• Identification of potential geological sites for storing CO2,
including types of geological storage (depletedhydrocarbon fields, deep saline formations, deep coalseams, etc.)• Assessment of “prospectivity" for CO2 storage (high,medium and low) by sedimentary basin and economy
Overview of Carbon Capture and Storage Activities in APEC
9

Focus of Phase I Assessment

Emissions based on IEA GHG Programme, 2002

Overview of Carbon Capture and Storage Activities in APEC
10

Sedimentary Basins in Asian APEC Economies

Overview of Carbon Capture and Storage Activities in APEC
11

Distribution of Large CO2 Stationary Sourcesin Asian APEC Economies

Overview of Carbon Capture and Storage Activities in APEC
12

Major CO2 Emission Centres
in Asian APEC Economies

Overview of Carbon Capture and Storage Activities in APEC
13

Sedimentary Basins Within 300 km of Major
CO2 Emission Centres in Asian APEC Economies

Overview of Carbon Capture and Storage Activities in APEC
14Distribution of 29 Sedimentary Basins in AsianAPEC Economies Evaluated in Phase I

 China17

 Indonesia

5 Republic of Korea 2
 Malaysia

2 Philippines1 Thailand1 Sabah1

Overview of Carbon Capture and Storage Activities in APEC
15

CO2 Emission Levels and Basin Prospectivity
in East Asian APEC Economies

Overview of Carbon Capture and Storage Activities in APEC
16

Ratio of CO2 Storage Capacity
in Hydrocarbon Reservoirs to CO2 Emissions

Overview of Carbon Capture and Storage Activities in APEC
17

Prospectivity for CO2 Geological Storage
in Selected Asian APEC Economies

Overview of Carbon Capture and Storage Activities in APEC
18

Summary of Phase I Study 29 out of more than 400 sedimentary basins in AsianAPEC Economies selected for assessment
 Deep saline aquifers are likely the best option for CO2
storage in at least 4 sedimentary basins in China
close to very large centres of CO2 emissions
 Hydrocarbon reservoirs are likely the best option forCO2 geological storage in Indonesia, Malaysia andThailand The Republic of Korea, Chinese Taipei and thePhilippines have limited potential for CO2 geologicalstorage

Overview of Carbon Capture and Storage Activities in APEC
19

Phases II and III – Capacity BuildingPhases II and III: 2004 – 2007

 Execution: Canadian team with international
partners

Objectives:–

Build awareness around the potential for the capture
and geological storage of CO2 in APEC economies by:• preparing and disseminating training materials• conducting and facilitating workshops in selected APEC
locations–

Enhance the capacity of developing APEC economies
to identify, assess and develop their own CCS projects

Overview of Carbon Capture and Storage Activities in APEC
20

Phases II and III – Capacity Building (Cont’d) Phase II and III results:–

Developed training materials for 2-day course:• Training manual (13 modules, 2 case studies)• Powerpoint presentations, adapted for each specific economy–

Conducted training workshops in:• Republic of Korea (Jan. 2005)• P.R. China (October 2006)• Mexico (May 2007)–

Attendance ranged from 35 to 75, comprising government
departments and agencies, industry, research institutes,
universities and private citizens–

Reviewed feedback and improved training materials–

Prepared strategy for community outreachOverview of Carbon Capture and Storage Activities in APEC
21

Phases II and III – Capacity Building (Cont’d)Training Modules:
•
•
•
•
•
•
•
•
•
•
•

CCS Overview
CO2 Capture: Post-Combustion
CO2 Capture: Pre-Combustion
CO2 Compression and Transportation
Storage Options for CO2
Screening and Selection of CO2 Storage Sites
Health, Safety and Environmental Issues
Performance Assessments
Legal, Regulatory and Public Opinion Issues
Economic Considerations of CCS
Clean Development Mechanism (CDM)

Detailed Case Studies:••

Weyburn (Canada)
Sleipner (Norway)
Overview of Carbon Capture and Storage Activities in APEC
22

CCS Example: The Weyburn - Midale CO2
Monitoring and Storage Project - Location

Weyburn

Overview of Carbon Capture and Storage Activities in APEC
23

The Weyburn - Midale CO2 Monitoring and Storage Project
Objectives•

to predict and verify the ability of oil reservoirs to securely and economicallycontain CO2 through a comprehensive analysis of various methodologies•

to develop monitoring and modeling methods to address the long-term
migration and fate of CO2•

Commercial enhanced oil recovery operations by EnCana and Apache•

CO2 supplied by 320-km pipeline from lignite gasification plant in North
Dakota; 26 Mt to be injected and stored over 25 years•

Phase I (2001-2004) completed; Final Phase (2007-2010) underway; total
budget $80 million (50/50 cash / in-kind)•

5 governments (Canada, US, Saskatchewan, Alberta, E.U.); more than 10energy-based industry and institutional sponsors (Canada, USA, EU, Japan);endorsed by IEA GHG R&D Programme•More than 80 researchers from 22 S&T organizations in 6 countries
Overview of Carbon Capture and Storage Activities in APEC
24

The Weyburn - Midale Project – Modeling Results¾ The geological “container” at Weyburn is highly effective:¾ Prediction of migration of CO2 outside the EOR area at
5000 years post-injection:– 27% of the injected CO2 moves outside the EOR area, but remains
within geological region or “area of study”:• 18% migrates to the geosphere below reservoir via waterphase• 9% migrates laterally within reservoir, but outside the 75 EOR
patterns• 0.02% moves to higher formations, but remains confined within
the EOR perimeter• 0.14% leaks via aging, abandoned wells• 0% enters potable aquifers near the surface
Overview of Carbon Capture and Storage Activities in APEC
25

Next Steps• A new Phase IV just approved by APEC; a Request for Proposal(RFP) will be issued by APEC within next two months• Scope of work will involve delivering two more training
workshops:
•

China

•

Second location to be determined• Collaboration is being sought with similar capacity-building
initiatives, e.g. by CSLF, APP, EC, UK and Australia• A proposed feasibility study of re-injecting and storing CO2,
normally released by off-shore natural gas production facilities insouth-east Asia, is being considered by APEC

Overview of Carbon Capture and Storage Activities in APEC
26

Thank you for your attention!

For more information, email Frank Mourits
at fmourits@nrcan.gc.ca

Overview of Carbon Capture and Storage Activities in APEC
27

Day 2 Tuesday 16 October 2007
Session 8: FBC/ USC/ IGCC/ CCS

Speech 7 US
GE’s Gasification & IGCC Technology Application in China

Mr. Jian-Feng Liu
Technical Director
Application Engineering, China
GE Energy Consulting
USHarmonious and Sustainable Coal Power Generation
APEC Clean Fossil Energy Seminar

G E G asification and IG C C Technology
Liu Jian Feng
TechnicalD irector
Application Engineering,China
G E Energy Consulting

Xian, China
October 15-17, 2007

IG C C Provides A C leaner C oalSolution
0.16

PM 10
SO 2
NOx

Lb/M M BTU

0.15
0.10

Average Recent
Perm it D ata

0.09

0.05

0.04
0.03

Best Individual
Plant
0.017

0.02
0.01 0.01

0.00

0.01

0.01
0.002

N G CC
Advanced IG CC
Source:G E internaldata,average of30 U S
PC /SC PC
perm its granted,applications and publicly
reported em issions

IG C C Environm entalBenefits V ersus
Best in C lass SupercriticalPulverized C oal• 33% less N O x• 75% less SO x
• 40% less PM 10

H g % Captured
90% +50 90%PC IG CCHg
30-40%Less

PC IG CC
W ater U sage

• 90% + H g rem oval
• 30% less w ater
• CO 2 capture readyG E Proprietary Inform ation

C O E com parison IG C C vs.SC PC
Cost of Electricity,c/kW h• Current 20-25% IG CC C APEX
prem ium im pedingcom m ercialization

11

IG C C capex $2400/kW
10.42

10

-14%
-8%

9

9.00

8

• Com parable CO E to SCPC at 10%
capex prem ium• Significantly low er SO X/N O X andM ercury em issions offset 10%
CAPEX prem ium for IG CC

76• M ulti-units needed to drive out cost
• Carbon capture drives IG C C CO E
low er than SCPC

7.31

5
4
Base

11

• IG C C ram ps up to CO E parity 1012 th units

6.68

6.25

N O x/SO x

Hg

Cost of Electricity,c/kW h

SC PC

IG C CIG C C capex $2150/kW
10.42

10
9

+4.5%

8.30

8
+5.1%

7
6

6.68

6.25

6.75

5
4
Base

N O x/SO x

Hg

SC PC

IG C CG E Proprietary Inform ation

IG C C - C leaner By D esign
Pollution Prevention

vs.

Pollution C ontrol
W ESP
C arbonInjection

Boiler
SCR

ESP/
FF

FF
FG D

CO 2

Pre-Com bustion
PM ,H g,Su,CO 2

IG CC

Pulverized C oal• G asification converts coalto syngas of prim arily C O
and H 2 containing less C O 2• G asification cleans the coalbefore it is burned
instead of cleaning up the pollution after it isproduced.
• C O 2 concentration in syngas is high (40% -50% )• Rem oving pollutants requires treating
100 tim es the gas volum e of an IG CC
plant.
• CO 2 concentration is low (~14% - 1/3
that of syngas)• H igher criteria & H APS em issions than an
average IG CC plant• Lim estone sulfur rem ovaladds 3% -4%
to CO 2 em issions• The IG C C C leaner C oaloption increases fueldiversity,reduces em issions,and increases siting
and perm itting flexibility.
• Syngas is cleaned to rem ove particulates and sulfur
prior to com bustion• Low N O x em ission due to advanced G T

G E Proprietary Inform ation

Technology Investm ent
M ark V Ie
Plant
C ontrols

O ptim ized Feed Injectors
O xygenSlurryA SU

Top View

PolishSlice

Section 1

Section 2

Section 3

Section 4

Section 5

Section 6

R efractory
G as Turbine

Syngas C ooler

Steam Turbine
G E Proprietary Inform ation

G E G asification & IG C C Experience Leadership• G asification leader since 1948 w ith
62 facilities operating w orldw ide• First coalgasification plant in 1978
• 27 gas turbines operating on
synthesis gas,1,000,000 operatinghours• IG CC leader:>3 G W w ith G Etechnologies• >6 centuries team gasification
experienceG E’s G asification Experience~ 120 G asifiers In O peration
76

Plants O perating
Plants in D esign orU nder Construction

25

TotalPlants
on AllFuels

TotalPlants
O n Solid Fuels

G E Proprietary Inform ation

G E’s G asification Technology Fit C hina M arket
Features and Benefits:
sim ple,reliable and econom ically viable
FEED PREPG ASIFICATIO N

G AS CLEAN U P

O xygenEN D PRO D U CTSElectricity

Feedstock:• Coal• H eavy O il
• Pet Coke
• Asphalt• O rim ulsion• N aturalG as• Refinery
W astes

U seful byproduct:
Vitrified Slag

 Feedstock and ProductFlexibility
 Sim ple,safe and clean
operating system H igh Efficiency

Com bined Cycle
Pow er Block

SulfurRem oval
Particulate
Rem oval

 Convert low value feedstock tovalue added products

 H igh Availability

Syngas
M ercury
Rem oval Extensive Com m ercial
Experience of Solids
G asification

Alternatives:• H ydrogen• Am m onia
• Chem icals• M ethanol• Fischer-Tropsch
Liquids (zerosulfur diesel) Cost Com petitive
 Environm entally Superior H P O peration Allow s H igh
Single Train Capacity
 H igh D om estic Content
 M inim um W ater
U se/D ischarge
 Short Project Cycle
G E Proprietary Inform ation

G E G asification Product
V ery soon

Today….

U S todayType:
Q uenchType:
Q uenchType:Q uench
Size:450ft3
Pressure:up
to 8.7M pa
SingleG asifierC apacity:
500-1000TPD

Size:
900ft3Pressure:
up to
8.7M pa
SingleG asifierC apacity:
15002000TPD

Type:R SC

Size:
1800ft3

Size:1800ft3
Pressure:
4.0 M pa

Pressure:
4.0-8.7M pa

SingleG asifierC apacity:~ 3000TPD

SingleG asifierC apacity:~4000TPD

H H
Fertilizers

M ethanol/D M E

H ydrogen

Large scale
M ethanol/D M E

Fuels

IG C CG E Proprietary Inform ation

G E 10 Year Plan for IG C C G T
G E IG C C 燃气轮机十年发展规划
燃烧技术

系统一体化
Integrated O xygen
G asifierCoal

O2

Integrated Air G asifier

G asificatio Coal
n
G as

H ot
H 2S
Rem ova
Parti
Particlcles
es l

H 2 -100%

H igh
PressureAir
Separatio
n

CCoal
oal
Feed
Feed
C oal Stock
Stock
To
To
G asifie
Stack
r
Steam
Steam StackSteam
Steam

H ot
Part-Part
icle
Clean
Up

Ge
n

AAiirr

GT
CC

Coal
G as
16%

ST
ST

GG

H 2S

HX

Supplem ental
Air
0%
50%
100
%

H eat
RecoverySteam
G eneratio
n

AAsh
sh

GGTT

GG

Ai
Airr
Air Extraction
Case
A
Case BCase
C

N atural G as
2%

System s

100%
50%
0%

C om bustion

N G Exhaust 102%CG Exhaust 116%

Air 100%

Low
He

G en
G as Turbine

7F
O utput
MW
60 H z

atin
gV

alu e
G

as

Flat-Rated
RegionN atu

10~ 20% Extra
O utput

9F
O utput
MW
50 H z
ral G
as

59 F
15 C
A m bient
Tem perature增强出力 O utput EnhanceSingle Train IG C C Plants
S107H S109H(60 H z) (50 H z)
N et O utput
460 M W 550M W
Therm al Eff.
50%
50%

下一代燃机联合循环 N ext
G eneration

G E – G lobalLeader for G T and IG C C Technology
G E是全球燃气轮机及IG C C技术的领先者 G E Proprietary Inform ation

C om bustion D evelopm ent C apability燃烧技术的研发 State-of-the-art com bustion developm ent
facility at G reenville,S.C.
在G reenville的一流的燃烧技术开发设施 Com bustor operating conditions duplicated at
FullFlow /Press/Tem p
全流/全压/全温度的燃烧室运行实验 O ver 25 yrs.experience testing low Btu
synthesis gas
超过25年的低热值合成气试验经验 At G E’s G lobalResearch Laboratory advanced concepts for single-digit N O x
在G E全球研发中心 – 先进燃烧技术开发，N O x排放可达一位数 200 + tests per yr w ith precision data acquisition
system s
每年使用精确数据采集系统进行200多次测试。
G E Proprietary Inform ation

H 2/IG C C Turbines Program“
The objective of this project is to designand develop a fuelflexible (coalderived
hydrogen or syngas)gas turbine for IG CC
and FutureG en type applications thatm eets D O E turbine perform ance goals.”
D O E G oals:• Perform ance:• +2 to 3 % pts efficiency by 2010
• +3 to 5 % pts efficiency (total)by 2015
• Com bustion• <3 ppm N O x by 2015
• Fuelflexibility -FutureG en & traditionalIG CC• Capitalcost <$1000/kW

G E’s D O E H 2/IG C C Turbines Program•Com bustion D evelopm ent (em issions focus)– N ew com bustion technology for IG CC & high H 2
fuels (e.g.,FutureG en)•Turbine Technology (efficiency & increasedm ass flow )– H igher com ponent efficiency w ith higher flow rates•M aterials Technology(support turbine higher
Tfire)– H igh tem perature m aterials and coatings in an
IG CC/H 2 environm ent•System s D esign– Perform ance and system design

C leaner Energy from C oal
G E Proprietary Inform ation

BP/Edison -M ission C arson H 2 Pow er Project – C arson,CA
Pet Coke IGCC w/EOR & Carbon Storage

H ydrogen Pow er Projects• EO R IG CC project w ith 500M W & long term CO 2
storage• Low CO 2 em issions cogen plant fueled w /H 2
from gasification of refinery petroleum coke &recycled w aste w ater
• U tilize advantaged fossilfuels (coal,petcoke)• Produce high H 2 fuelgas to burn in gas turbines• Capture CO 2 (~90% )• U tilize CO 2 for Enhanced O ilRecovery (EO R)• Future storage in Saline Aquifers• Pow er: 1x207FB Com bined Cycle Plant• G asifier:900ft quench w ith deep sulfur rem oval
AG R
• Value Through Collaboration• Com bine technology com pany w ith anoperations com pany
Carson H ydrogen Pow er Project• Leaders in gasification,pow er and CCS• 10 – 15 projects over next decade• Carson,CA is first gasification project
G E Proprietary Inform ation

Exam ple IG C C Plant Interfaces D iagram
N um erous Process Integration Stream s.
O verallSystem Integration C rucialIn M eeting Plant LevelG oals.

G E is The Experience Leader in IG C C System Integration
G E Proprietary Inform ation

G E M ultiple IG C C O fferings
IG CC Reference Plant – G E and Bechtel’s IG C C Alliance• Structured product – nom inal630 M W• G E to integrate alltechnologies used plantw ise• Single point solution – fullw rap & perform ance guarantees• RAM O ptim ization
IG CC N on-Reference Plants• Custom IG CC pow er plants• Co-production – polygen applications(pow er,steam ,H 2,m ethanol,FT liquids)• Perform ance guarantees• M ultiple EPCs
IG CC Pow er Block Supply• Allgasification technologies
N G CC to IG C C FuelC onversion Projects• U nder-utilized assets• IG CC perform ance guarantees possible w /G E pow er blocks
G E Proprietary Inform ation

G E Launches 630M W IG C C in 60H Z U S M arket• N om inal630M W net plant output

Key U S C riticalto Q uality (C TQ )Factor for Reference Plant:• 7FB gas turbine com bined
cycle system• Low em ission,• C A PEX-SC PC + 25% ,R eference plant design• Fuelflexibility• H igh availability efficiency sam e or
– W ide range of bitum inous coals
better than SC PC .
– C oal/coke blends• C O 2 capture capability in the future
Key Reference Plant C oalProperties:•Sulfur:0.74-4%•A sh:up to 14%•C hlorides:up to 2,500 ppm

G E Proprietary Inform ation

800MW IGCC Power Plant Conceptual Proposal
GE Quench Gasifier + 209F Combined Cycle Unit

Coal

G asification
Island(4 G asifier trains)

4x900 ft3
Q uench G asifier

Coal

Pow er Island(209F)
1x209F or
2x109F-M S

G asification
Island(2xG asifier trains)

Pow er Island(209F)

2x1800 ft3
Q uench G asifier

1x209F or
2x109F-M S

Features & Benefits (900ft3)> W idely applied in China> H igh levelofdom estic equipm ent supply> Localengineering capability> Short project schedule> Low capitalcost> H igh availability> Suprem e environm entalPerform ance
> Pressure up to 8.7M pa> CoalRate:up to 2000 TPD per gasifier> Com m ercialexperience of w ide rage ofcoals> Extensive experience ofcom bined cycle> System integration expertise> Effective im plem entation for CO 2 capture
Features & Benefits (1800ft3)> Large gasifier m ore costeffective>H igh levelofdom estic
equipm ent supply> Target to m arket 2008
> CoalRate:up to 4000 TPD per gasifier
3 quench
G EtPropri
etary Inform ation>O thers are the sam e as 900f

800MW IGCC Power Plant Conceptual Proposal
3xGE Radiant Gasifier+209F Combined Cycle Unit

Gasifier

9F

HRSG

Gasifier
STG
9F

HRSG

Gasifier

Proven technology
M ore flexible
M ore available

D esign: Pressurized,singlestage,dow nw ard
firing, entrained flow ,slurry feed,oxygen
blow n,slagging,radiant and quench
cooling
Feed Rate:about 6000TPD
Pow er:S209F
G E Proprietary Inform ation

G E G asification C om m ercialization Process
Pilot

D em oCom m ercial(China) W ison Coal to M ethanol/C O

Started gasification
licensing business in C hina
in late 1970’s,First coalplant started up
in 1994.
Totallicense till3Q 2007:(China) N CIC Coal/Coke to Am m onia

Sinopec Jinling(China) H aolianghe Coal to Am m onia / U rea

H aolianghe

250M W (U SA) Coal to Pow er(China) W eihe Coal to Am m onia / U rea

Solid Feed G asifiers:62
C om m ercialO peration:30
U nder C onstruction:32
(China) SCCC Coal to Tow n G as / M ethanol
.

Lunan

SA R
U BE
C oolW ater
Eastm an

25sTPD plant at
M ontebello U SA
research lab

TVA
RA G /RC H

1970

ED P,Farm land,D C RP

(China) H uainan Coal to Am m onia / U rea

Solid Feed:22
Liquid Feed:8
G as Feed:2

Sinopec N C IC

(China) Jinling Coal/Coke to Am m onia /H 2

(U SA) Coke to Pow er / Am m onia/H 2

32

W ison N anjing

H uainan
TEC O

W eiheShanghai(China) Coal to Am m onia

(G erm an) Coal to O xo-chem /H 2

(Japan) Coal and Petroleum Coke to Am m onia

120M W (U SA) Coal to Pow er(U SA) Coal to M ethanol / Acetic Anhydride(U SA) Coal to Am m onia

(G erm an) Coal to O xo-chem icals

1980

1990

2000

2007

G E Proprietary Inform ation

G E G asification Projects in C hina
Total15
signed in thepast 5 yrs

Totalllll3Q
Totallilcense
icensetiti
3Q2007:
2007:32
32
Sol
i
d
Feed:
22,
Li
qui
d
Feed:
Solid Feed:22, Liquid Feed:8,
8,
GGas
Feed:
2
as Feed:2
Sol
ididFeed
fifi
ers:
Sol
FeedGGasi
asi
ers:62
62
handl
es
handl
estotaltotal50KTPD
50KTPD of
ofcoal
coal
wwhi
ch
hi
ch18M
18MMMTPY
TPYof
ofcoalcoal
CComm
ercialO
peration:om m ercialO perati
on:30
30
UUnderC
onstructi
on:32
nder C onstruction:32
G E Proprietary Inform ation

Extensive C om m ercialExperience in C hina
W e now have 900ft3
quench gasifier handles
up to 2000TPD of CoalU p to 8.7M pa operationpressure running w ith
fast schedule and low
cost for chem ical
projects

ShanxiShenm u C hem ical
Licensed in:2003,Startup:2005
C oalSource:localcoal,
Feed Rate: 1,000 TPD
O peration Pressure:40 Bar,G asifier Size:450 ft3

Sinopec Jinling
Licensed in:2002,Startup: 2005
Feedstock:Coal/Pet-coke,Feedrate:2,200 TPD
O peration Pressure:40 Bar,G asifier Size:900 ft3

W ison (Shanghai)
Licensed in:2004,Startup:2007,2Q
Feed rate:1,500 TPD ,Feedstock:C oal/C oke
O peration Pressure:65 Bar,G asifier Size:450 ft3

Sinopec,N anjing
icensed in:2003,Startup:1Q /2006
Feedstock:C oal/Pet-coke,Feed rate:
1,400 TPD ,O peration Pressure:87 Bar,G asifier Size:900 ft3• 18 ~ 24 m onths from license signing– to m echanicalcom pletion• 24 ~ 30 m onths from license signing– to start-up• Established Eng D elivery• D edicated Start-up Support• Experienced Engineering Firm
Inform ation• M anagem ent ComG EmPropri
itmetaryentof O w ner

Sound A vailability & R eliability R ecords –Solids G asification in C hina
A vailability 2003

2004

100%

C hinaG EG P/C oal
Four Plants

2005

2006*
90%

80%
60%
40%
20%

A vailability = (1(unplanned outage+planned outage)/8760)*100%

0%

1

2

3

4

1

2

3

4

1

2

3

4

1

2

3

4

R eliability
2003

100%
Reliability = (1(unplanned outage) 80%/8760)*100%
60%

2004

2005

2006*

90%

40%
20%
0%

1

2

3

4

1

2

3

4

* Accounting period for Plant # 3 is betw een Jan to O ct.

1

2

3

4

1

2

3

4

G E Proprietary Inform ation

G E Syngas Experience by A pplication

27xG T O perating w ith O ver 1,000,000 O peration H ours on Syngas
G E Proprietary Inform ation

G E Experience on Syngas & H igh H ydrogen FuelGE LBTU Fuel Experience:Tampa Electric - Florida
250 MW Fuel: Coal/PetCoke
GE Gasification- 3+ GW Installed (15 Plants)- 27 Gas Turbines with Syngas- Over 1,000,000 Operating Hours- Plants in USA, Germany, Italy, Canada,
Netherlands, Singapore, Czech Rep.,
China

G E H igh H ydrogen Experience

Wabash - Cinergy
250 MW Fuel: Coal/Pet CokeCoP Gasification

Vresova –Czech Republic
350 MW Fuel: Brown Coal
Lurgi Gasification

C ustom er/ Site
ExxonM obilSingapore
G eorgia G ulf
SU V Vresova
BASF/ G eism er

M odelM S6001FA
M S7001EAM S9001E
M S6001B

Antw erpen
Puertollano
La Coruna
Rotterdam
AG IP/ M ilazzo
Cochin Refineries
M obil/ Paulsboro
U hde N U P
D onges
Zarqa Refinery

M S6000B
M S6000B
M S6000B
M S6000B
M S5001P
M S5001P
M S5001P
M S3002J
G E10
PG T10N o. G as Features
2 IG CC 44.5% H 2
3 Blend M ethane+50% H 2
2 IG CC 46.8% H 2
1
PG U p to 80% H 2

1
2
1
1
1
1
2
1
1
1

RFG
RFG
RFG
RFG
RFG
RFG
RFG
TG
RFG
RFG

78% H 2U p to 60% H 2
U p to 52% H 2
59% H 2
30% to 50% H 2
50% H 2
20% to 60% H 2~60% H 2
76% H 2
82% H 2G E Proprietary Inform ation

Low Btu G T Experience in C hina

ecom agination SM
a G E com m itm ent

低热值燃气轮机在中国的应用经验Jinan Steel
2004/2006

Bao Steel2007

Chongqing Steel2006

50M W 1x106B
通化Tonghua
100M W 2x106B
济南Jinan
300M W 6x106B
济南Jinan
50M W 1x106B
重庆C hongqin
上海宝钢Baosteel175M W 1x109E
福建炼化FJ Refinery 300M W
2x9E
2x9E
武汉钢厂W uhan 220M W

Tonghua Steel2003

Sichuan

2003
2004
2006
2006
2007
2008
2009

Fujian Refinery
2008

G E Proprietary Inform ation

Cooperation with HPEC, NTC and LM for GT Production
同哈尔滨电站设备公司和南京汽轮电机公司,沈阳黎明航空发动机厂合作

G E Proprietary Inform ation

Investing for Success$40Y(est.)
300

H eadcount

20X+ProductD evelopm ent
Budget
$20Y
$15Y
$Y

Avg/yr
‘
01–‘
04

250
200
150

5

g
n
i
f
f
a
t
Xs

100
50
0

‘
05

‘
06

‘
07

Jun04

D ec05

D ec06

G asification Program s•H igh Efficiency Sulfur Rem oval •Syngas Cooler Advanced D esign•Advanced Q uench Ring
•Advanced Feed Injector•Advanced Refractory•Low Rank CoalD esign

G E Proprietary Inform ation

Sum m ary• Proven technology – Both G asification and IG CC incom m ercialoperation today• G asification flexible feedstock,easy operation,short cycle• Proven G as Turbine for m atching w ith G E’s quench,RSC
gasification and other technologies• H igh availability and reliability• G E is the only com pany now has com m ercially provenadvanced gasification and G TCC technology and productas w ellas system integration for IG CC project.

G E Proprietary Inform ation

Day 2 Tuesday 16 October 2007
Session 8: FBC/ USC/ IGCC/ CCS

Speech 8 Japan
CO2 Recovery from Power Plant using Oxy-fuel Combustion System
Feasibility Study & Combustion Test Results

Mr. Keiichiro Hashimoto
Manager
Boiler & Environmental Group
Research & Development Department
Power Plant Division
IHI CorporationJapanAPEC 2007
Clean Fossil Energy Seminar
15-17 October 2007, Xian, China

CO2
CO2 recovery
recovery fromfrom PowerPower plant
plant
using
using Oxy-fuelOxy-fuel combustion
combustion systemsystem-Feasibility-Feasibility study
study andand combustion
combustion test
test resultsresults-

Keiichiro Hashimoto
IHI Corporation1

Approach to reduce CO2

1

Save Energy use

Improvement in Efficiency
Co-Generation

2

Use of renewable Energy

Use of Biomass as FuelWind Power
Solar Power3

CO2 Recovery

etc

CO2 Separation / Capture
CO2 Storage

Improvement in Efficiency

1

A-USC Boiler

Development of Steam Condition in Japan
Tachibanawan-No.1
610C (1,130F)

STEAM TEMP.

600

700C
700C
620

610

31.0

30
593

500

450

STEAM PRESS. ( MPa )S TEA M TEMP.
STEAMTEMP . [ o C(F)]

550

25

~~

566
538
24.1

610 C (1,130F)
Isogo-No.1

20
15

482

593C (1,100F)
Hekinan-No.3

485
16.6

Isogo-No.2

450
10

STEAM PRESS.

4.1
5

~

400
‘55

‘60

‘65

‘70

‘90

Year of Initial Operation

‘95

2000

2

Use of Biomass as Fuel

CFB-Boiler

Use of renewable fuel in Circulating Fluidized Bed boiler
Steam Drum

HRA

RPF
RPF

CycloneEVA
PSH࿑㪈 ⴫㪊 䊗䉟䊤᷷ᐲ․ᕈᕈ⢻⹜㛎⚿ᨐ

Wood
WoodChip
Chip

Cyclone

The separation of Particle andSSH
corrosive
Combustion gas

FurnaceECO

Slidreturn leg

GAH

EHE

Waste
WasteTire
Tire
etc…
etc…
CFB
CFBboiler
boiler

TSH&FSH

External Heat Exchanger-To isolate high temp. SH fromcombustion gas including Chlorine-Heat Exchange of high temp. particle䋩
Reference䌾 Oj.,Ltd䋨CFB boiler
Ojii Paper Co
Co.,Ltd䋨CFB
boiler䋩

Steam Flow

260t/hSteam Condition 12.35MPa/569é

Fuel
RPF/Coal/Waste fuelBoiler Efficiency (LHV base) 92.96%
SOx
8ppm 䋨㶎1䋩
NOx
94ppm䋨㶎2䋩
Particulates
0.6mg/Nm3 䋨㶎3䋩CO
23ppm 䋨㶎3䋩Dyoxin0.1ng-TEQ/Nm3 䋨㶎3䋩䋨㶎1䋩dry, actual O2䋨㶎2䋩 dry, O2 6%conv.
䋨㶎3䋩dry, O2 12%conv.

3

CO2 Separation / Capture

Oxy Fuel Boiler

Oxy-fuel combustion technology
Oxy-fuel(1)

CO2 capture systems(2)

IHI Oxy-fuel combustion system(3)

Development schedule(4)

Oxy-fuel Pilot Scale Testing(5)

Callide A Demonstration Project(6)

Study of 1000MWe Oxy-fuel PCF

(1) CO2 Capture systems㪦㫏㫐㪄㪽㫌㪼㫃㩷㪚㫆㫄㪹㫌㫊㫋㫀㫆㫅
Coal
N2

BoilerFlue gas
treatment

Non-condensable
gas
CO2
storage

CO2䋬H2O䋬O2Air
O2Oxygenproduction unit

H2O
compression/cooling

Flue gas recirculation

N2䋬H2O䋬O2

㪧㫆㫊㫋㪄㪚㫆㫄㪹㫌㫊㫋㫀㫆㫅
Coal

BoilerFlue gas
treatment
N2, CO2 ,CO2

CO2storageAir

H2O, O2
CO2separation

compression/cooling㪞㪸㫊㫀㪽㫀㪺㪸㫋㫀㫆㫅
Coal
N2
Air
O2
Oxygenproduction unit

Gasification

Flue gas
Shift reactor
treatment

H2

Use of H2(for power generation)
CO2
CO2
storage

CO,

CO2,

H2

H2
CO2separation

compression/cooling(2) IHI Oxy-fuel combustion system
System : Direct CO2 capture
N2

P.C.
(C, H…)

Boiler

(CO2,
H2O…)

CO2 capturesystem
CO2

Air(N2, O 2)

O2

Air separation
unit(CO2, H2O…)

H2O…

Flue gas recirculation

Features䊶Direct CO2 capture.
䊶Higher plant efficiency is expected for CO2 capture.
䊶Flue gas treatment equipment are small-sized or non-installed.
䊶NOx and SO2 emissions are reduced greatly.

(3) Development schedule
Items

'90

J-Power / IHI Joint
Study

Basic test

'91

'92

'93

'94

'95

'96

'97

'98

'99

'00

'01

'02

'03

'04

'05

'06

Liquefaction of flue gas
Behavior of NO䌸/SO䌸

NEDO “EnvironmentFriendly Coal
Combustion Technology– Oxy-fuel Combustion
Technology-”(CCUJ / J-Power /Nippon Sanso / IHI)

Ignition & propagation under micro-gravity
Combustion test In-furnace desulfurization
Combustion simulation

System of Oxy-fuel power plantOperation method
Plant simulation

CO2 capture from IGCC system

NEDO “Application of
Oxy-fuel Combustion
Technology to existing
Pulverized Coal-fired
Power Plants” (JCOAL/ J-Power / IHI)

Site selection / Modification items/ Economy & Efficiency
Modification items /Operationablity /Economy & Efficiency

Feasibility study
under AustraliaJapan joint project

'07

'08

(4) Oxy-fuel Pilot Scale Testing 㽲㪫㪼㫊㫋㩷㪽㪸㪺㫀㫃㫀㫋㫀㪼㫊㪚㫆㫄㪹㫌㫊㫋㫀㫆㫅㩷㪚㪸㫇㪸㪺㫀㫋㫐㪑㩷㫄㪸㫏㪅㩷㪈㪌㪇㫂㪾㪆㪿㪝㫌㫉㫅㪸㪺㪼㪑㩷㪭㪼㫉㫋㫀㪺㪸㫃㩷㫋㫐㫇㪼㪠㪅㪛㪅㩷㪈㪅㪊㫄㩷㬍 䌌 㪎㪅㪌㫄㪙㫌㫉㫅㪼㫉㪑㩷㪪㫎㫀㫉㫃㩷㫇㫌㫃㫍㪼㫉㫀㫑㪼㪻㩷㪺㫆㪸㫃㩷㪹㫌㫉㫅㪼㫉㪧㪘㪝㪁㪪㫐㫊㫋㪼㫄㩷㫎㪸㫊㩷㫊㫀㫄㫌㫃㪸㫋㪼㪻㩷㪹㪸㫊㪼㪻㩷㫆㫅㩷㪸㪺㫋㫌㪸㫃㩷㫄㫆㪻㫀㪽㫀㪺㪸㫋㫀㫆㫅㩷㫋㫆㩷㪦㫏㫐㪄㪽㫌㪼㫃㪅㪜㫃㪼㪺㫋㫉㫀㪺㪸㫃㩷㪿㪼㪸㫋㪼㫉

㪧㫌㫃㫍㪼㫉㫀㫑㪼㪻㩷㪺㫆㪸㫃㪝㫌㫉㫅㪸㪺㪼
㪞㪸㫊㩷㪺㫆㫆㫃㪼㫉

㪘㫀㫉㩷㪿㪼㪸㫋㪼㫉

㪞㪸㫊㩷㪺㫆㫆㫃㪼㫉

㪙㪸㪾㩷㪽㫀㫃㫋㪼㫉

㪪㫋㪸㪺㫂
㪠㪛㪝

㪘㫀㫉
㪜㫃㪼㪺㫋㫉㫀㪺㪸㫃㩷 㪪㫋㪼㪸㫄㩷㪾㪸㫊㩷 㪮㪸㫋㪼㫉㩷㫊㫇㫉㪸㫐㩷㫋㫆㫎㪼㫉㪿㪼㪸㫋㪼㫉
㪿㪼㪸㫋㪼㫉

㪧㪿㫆㫋㫆㩷㫆㪽㩷㫋㪼㫊㫋㩷㪽㪸㪺㫀㫃㫀㫋㫀㪼㫊㪝㪛㪝㪆㪞㪩㪝

㪪㫐㫊㫋㪼㫄㩷㪺㫆㫅㪽㫀㪾㫌㫉㪸㫋㫀㫆㫅㪦㪉㪝㫌㫉㫅㪸㪺㪼㩷㫊㫀㫄㫌㫃㪸㫋㫀㫆㫅
㪘㫀㫉

㪦㫏㫐㩷㪈

㪦㫏㫐㩷㪉

㪫㫆㫋㪸㫃㩷㪾㪸㫊㩷㪽㫃㫆㫎㩷 㪈㪋㪉㫋㪆㪿㩷㩷㩷㪈㪈㪎㫋㪆㪿㩷㩷㩷㩷㩷㪈㪋㪇㫋㪆㪿㪫㫆㫋㪸㫃㩷㪦㪉 㪺㫆㫅㪺㪅㩷㩷㩷㩷㩷㩷㪉㪈㩼㩷㩷㩷㩷㩷㩷㪊㪇㪅㪉㩼㩷㩷㩷㩷㩷㩷㩷㩷㪉㪍㪅㪌㩼㪦㫏㫐㩷㪊㪈㪎㪇㫋㪆㪿
㪉㪈㪅㪎㩼㪝㪜㩷㪞㪸㫊㩷㪫㪼㫄㫇㪅㪙㪸㫊㪼㩷㩷㩷㩷㩷㪣㫆㫎㪼㫉㩷㩷㩷㪥㪼㪸㫉㫃㫐㩷㪼㫈㫌㪸㫃 㪟㫀㪾㪿㪼㫉㪟㪼㪸㫋㩷㪸㪹㫊㫆㫉㫇㫋㫀㫆㫅 㪙㪸㫊㪼㩷㩷㩷㩷㩷㪟㫀㪾㪿㪼㫉㩷㩷㩷㪥㪼㪸㫉㫃㫐㩷㪼㫈㫌㪸㫃 㪣㫆㫎㪼㫉㪝㫌㫉㫅㪸㪺㪼㩷㪿㪼㪸㫋㩷㪸㪹㫊㫆㫉㫇㫋㫀㫆㫅㩷㩿㪤㪮㪀

Oxy-fuel Pilot Scale Testing 㽳㪘㫀㫉㩷㪺㪸㫊㪼
㪦㫏㫐㩷㪺㪸㫊㪼

㪎㪇
㪍㪇
㪌㪇
㪋㪇
㪊㪇
㪉㪇

㪪㫀㫄㫌㫃㪸㫋㫀㫆㫅㩷㫉㪼㫊㫌㫃㫋㫊㩷㫆㪽㩷㪿㪼㪸㫋㩷㪸㪹㫊㫆㫉㫇㫋㫀㫆㫅

㪘㫀㫉

㪦㫏㫐㩷㪈

㪉㪌

㪊㪇

㪦㪉㩷㪺㫆㫅㫋㪼㫅㫋㩷㫆㪽㩷㫋㫆㫋㪸㫃㩷㪾㪸㫊㩷㩿㫎㪼㫋㫍㫆㫃㩼㪀

㪦㫏㫐㩷㪉

㪦㫏㫐㩷㪊

㪊㪌

Oxy-fuel Pilot Scale Testing 㽴
Coal

㪚㫆㪸㫃㩷
㪸㫅㪸㫃㫐㫊㫀㫊

HHV

Coal A

Coal B

Coal C

23.7

27.9

30.0

[air dry%][dry%][dry%][dry%]

8.8
19.3
25.7
55.0

4.1
18.2
40.9
40.9

14.0
6.9
34.1
59.0

[dry%][dry%][dry%][dry%][dry%]

63.5
2.8
0.73
13.5
0.24

65.6
5.3
0.72
9.7
0.57

74.4
4.2
1.91
11.8
0.88

Air mode

Oxy mode

Proximate Analysis

IM
Ash
VM
FC
Ultimate analysis
C
H
N
O
S

㪚㫆㫄㪹㫌㫊㫋㫀㫆㫅㪺㫆㫅㪻㫀㫋㫀㫆㫅㫊㿽
[dry·MJ/kg]

Combustion mode㿽Heat input

MWt

0.8 – 0.48

Fineness% under 74µm

75Flue gas O2 at AH inlet

dry%

3.5 - 4.3

Wind-box O2

wet%

21 (Air)

35

Primary O2wet%

21 (Air)

3.5 – 4.3

wet%, calc

21 (Air)

27

Total O2 content to furnaceOxy-fuel Pilot Scale Testing 㽵㪟㪼㪸㫋㩷㪽㫃㫌㫏㩷㪸㫋㩷㫋㪿㪼㩷㫉㪸㪻㫀㪸㫋㫀㫆㫅㩷㫊㪼㪺㫋㫀㫆㫅
㪊㪇㪇㪦㫏㫐㪄㪽㫌㪼㫃
㉄⚛Ά὾
㪘㫀㫉
ⓨ᳇Ά὾

㪈㪏㪇㪇
㪝㫃㪸㫄㪼㩷㫋㪼㫄㫇㪅㩷㩿㪻㪼㪾㫉㪼㪼㩷㪚㪅㪀㪟㪼㪸㫋㩷㪽㫃㫌㫏㩷㩿㫂㪮㪆㫄㪉㪀ᾲᵹ᧤㩷㩿㫂㪮㪆㫄㪉㪀

㪉㪌㪇
㪉㪇㪇
㪈㪌㪇
㪈㪇㪇
㪌㪇
㪇
㪇㪑㪇㪇

㪝㫃㪸㫄㪼㩷㫋㪼㫄㫇㪼㫉㪸㫋㫌㫉㪼㪚㫆㪸㫃㩷㪙㪆㪦㫏㫐㪚㫆㪸㫃㩷㪙㪆㪘㫀㫉

㪈㪎㪇㪇
㪈㪍㪇㪇
㪈㪌㪇㪇
㪈㪋㪇㪇
㪈㪊㪇㪇
㪈㪉㪇㪇
㪈㪈㪇㪇
㪈㪇㪇㪇

㪇㪑㪉㪇
㪇㪑㪋㪇
⚻ㆊᤨ㑆䋨㪿䋩
㪫㫀㫄㪼㩷㩿㪿㪀

㪈㪑㪇㪇

㪐㪇㪇
㪇

㪈
㪉
㪊
㪋
㪌
㪍
㪛㫀㫊㫋㪸㫅㪺㪼㩷㪽㫉㫆㫄㩷㪹㫌㫉㫅㪼㫉㩷㫋㪿㫉㫆㪸㫋㩷㩿㫄㪀㪜㫏㫇㪼㫉㫀㫄㪼㫅㫋㪸㫃㩷㫉㪼㫊㫌㫃㫋㫊㩷㫊㪿㫆㫎㫊㩷㫋㪿㪼㩷㫊㪸㫄㪼㩷㪿㪼㪸㫋㩷㪽㫃㫌㫏㩷㪹㫆㫋㪿㩷㪸㫀㫉㩷㪸㫅㪻㩷㫆㫏㫐㩷㪺㫆㫄㪹㫌㫊㫋㫀㫆㫅㩷㫄㫆㪻㪼Oxy-fuel Pilot Scale Testing 㽶㪚㪦㪉㩷㪺㫆㫅㪺㪅㩷㪻㫌㫉㫀㫅㪾㩷㫋㪿㪼㩷㫋㪼㫊㫋㪚㪦㪉㩷㪺㪸㫇㫋㫌㫉㪼㪁㪧㫆㫊㫀㫋㫀㫍㪼㩷㪽㫌㫉㫅㪸㪺㪼㩷㫇㫉㪼㫊㫊㫌㫉㪼㪁㪏㪌䌾㪐㪌㩼㩷㪚㪦㪉 㪺㫆㫅㪺㪅㪁㪚㫆㫅㫅㪼㪺㫋㩷㫋㪿㪼㩷㪺㫆㫄㪹㫌㫊㫋㫀㫆㫅㩷㫋㪼㫊㫋㩷㪽㪸㪺㫀㫃㫀㫋㫀㪼㫊㩷㫎㫀㫋㪿㩷㫋㪿㪼㩷㪽㫃㫌㪼㩷㪾㪸㫊㩷㪺㫆㫄㫇㫉㪼㫊㫊㫆㫉㩷㫌㫅㫀㫋㪁㩷㪚㪦㪉㩷㫉㪼㪺㫆㫍㪼㫉㩷㫌㫅㪻㪼㫉㩷㫋㪿㪼㩷㪺㫆㫅㪻㫀㫋㫀㫆㫅㩷㫆㪽㩷㪇㷄䋯㪎㪤㪧㪸

㪙㩷㪺㫆㪸㫃
㪚㩷㪺㫆㪸㫃
㪛㩷㪺㫆㪸㫃

㪈㪇㪇㪚㪦㪉㩷㪺㫆㫅㪺㪅䋨㪻㫉㫐㩼䋩㪐㪌㪐㪇㪙㫆㫌㫅㪻㪸㫉㫐㩷㫊㫌㫉㪽㪸㪺㪼

㪏㪌
㪏㪇
㪎㪌
㪎㪇
㪉㪅㪌

㪊㪅㪇
㪊㪅㪌
㪋㪅㪇
㪝㫃㫌㪼㩷㪾㪸㫊㩷㪦㪉㩷㪺㫆㫅㪺㪅䋨㪻㫉㫐㩼䋩㪁㪧㫆㫊㫀㫋㫀㫍㪼㩷㪽㫌㫉㫅㪸㪺㪼㩷㫇㫉㪼㫊㫊㫌㫉㪼㪋㪅㪌㪣㫀㫈㫌㫀㪻㩷㪚㪦㪉Oxy-fuel Pilot Scale Testing 㽷㪝㫃㪸㫄㪼㩷㫊㫋㪸㪹㫀㫃㫀㫋㫐㪇㪅㪏㪤㪮㫋

㪝㫃㪸㫄㪼㩷㫀㫊㩷㪹㫃㫆㫎㫅㩷㫆㫌㫋㩷㪽㫉㫆㫄㩷㫋㪿㪼㩷㪹㫌㫉㫅㪼㫉㩷㫋㪿㫉㫆㪸㫋㩷㪸㫋㩷㫋㪿㪼㩷㪹㫌㫉㫅㪼㫉㩷㫃㫆㫎㩷㫃㫆㪸㪻㩷㫆㫇㪼㫉㪸㫋㫀㫆㫅㪅㪇㪅㪍㪋㪤㪮㫋

䊶㪪㫌㫇㫇㫆㫉㫋㩷㫆㪽㩷㪻㫀㫉㪼㪺㫋㩷㪦㪉㩷㫀㫅㫁㪼㪺㫋㫀㫆㫅䊶㪣㫀㫄㫀㫋㪸㫋㫀㫆㫅㩷㫆㪽㩷㫃㫆㪸㪻㩷㫉㪸㫅㪾㪼
Primary air/ gas㪇㪅㪋㪏㪤㪮㫋

Secondary
air / gas
Wind-box
Air register㪘㫀㫉㩷㫄㫆㪻㪼
Furnace㪦㫏㫐㩷㫄㫆㪻㪼

Oxy-fuel Pilot Scale Testing 㽸㪚㫆㫄㪹㫌㫊㫋㫀㫆㫅㩷㪺㪿㪸㫉㪸㪺㫋㪼㫉㫀㫊㫋㫀㪺㫊㪪㪦㪉㪃㩷㪦㫏㫐㩷㫄㫆㪻㪼㩷䋨㫄㪾㪆㪤㪡䋩

㪊㪇㪇
㪉㪇㪇
㪈㪇㪇
㪇

㪋㪇㪇

㪊㪇㪇

㪉㪇㪇

㪈㪇㪇

㪇

㪈㪇㪇

㪉㪇㪇

㪊㪇㪇

㪋㪇㪇

㪇

㪌㪇㪇

㪌
㪋
㪊
㪉
㪈
㪇

㪇
㪈㪇㪇

㪉㪇㪇

㪊㪇㪇

㪋㪇㪇

㪇

㪌㪇㪇

㪉

㪋

㪍

㪏

㪚㪸㫉㪹㫆㫅㪄㫀㫅㪄㪸㫊㪿㪃㩷㪘㫀㫉㩷㫄㫆㪻㪼㩷㩿㩼㪀㪪㪦㪉㪃㩷㪘㫀㫉㩷㫄㫆㪻㪼㩷㩿㫄㪾㪆㪤㪡㪀㪥㪦㫏㪃㩷㪘㫀㫉㩷㫄㫆㪻㪼㩷㩿㫄㪾㪆㪤㪡㪀㪎㪇㪍㪇㪘㫊㪿㩷㪺㪿㪸㫉㪸㪺㫋㪼㫉㫀㫊㫋㫀㪺㫊㩷㩿㪺㫆㪸㫃㩷㪘㪀

㪘㫊㪿㩷㪸㫅㪸㫃㫐㫊㫀㫊㩷㩿㫎㫋㩼㪀㪥㪦䌸㪃㩷㪦㫏㫐㩷㫄㫆㪻㪼㩷䋨㫄㪾㪆㪤㪡䋩㪋㪇㪇㪚㫆㪸㫃㩷㪘
㪚㫆㪸㫃㩷㪙
㪚㫆㪸㫃㩷㪚

㪍㪚㫆㪸㫃㩷㪘
㪚㫆㪸㫃㩷㪙
㪚㫆㪸㫃㩷㪚

㪌㪇㪇㪚㪸㫉㪹㫆㫅㪄㫀㫅㪄㪸㫊㪿㪃㩷㪦㫏㫐㩷㫄㫆㪻㪼㩷䋨㩼䋩㪚㫆㪸㫃㩷㪘
㪚㫆㪸㫃㩷㪙
㪚㫆㪸㫃㩷㪚

㪌㪇㪇

㪌㪇
㪚㫆㪸㫃
㪝㫃㫐㩷㪸㫊㪿㩷㪆㩷㪦㫏㫐㪝㫃㫐㩷㪸㫊㪿㩷㪆㩷㪘㫀㫉

㪋㪇
㪊㪇
㪉㪇
㪈㪇
㪇
㪪㫀㪦㪉 㪘㫃㪉㪦㪊 㪝㪼㪉㪦㪊 㪚㪸㪦

㪤㪾㪦

㪫㫀㪦㪉

㪥㪸㪉㪦

㪢㪉㪦

㪧㪉㪦㪌

㪪㪦㪊

㪤㫅㪦

㪣㫀㪉㪦

㪈㪇

(5) Callide A Demonstration Project 㽲
CO2 storage site
*Type: Depleted gas reservoir*Capacity: Approx. 13million t-CO2*Approx. 250km west of power station
GalileeBasin

GalileePower Plant

Nth Denison
Trough*Callide-A: 4 units x 30 MWe*Evaporation:
123 t/h steam at 4.1 MPa,
460oC
*Commissioned: 1965 – 69
*Refurbished 1997/98

Greater Denison TroughWunger Ridge
Wunger Ridge
Roma Shelf
Roma Shelf

Callide-A PS

Callide A Demonstration Project 㽳Project Schedule
Task

2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016

Stage 1 - Boiler refurb/retrofit
Project development
Finalisation of contracts
Site preparation and final detailed design
Unit 4 refurbishment
Operation - air-firing
Oxyfuel retrofit
Operations oxy-firing
Stage 2 - Geological storage
Site selection
Detailed design & permitting
Field works construction
Injection & monitoring
Stage 3 - Project conclusion
Post monitoring & rehabilitation +Commercialisation.

㪪㫋㪸㪾㪼㪈䋭㪙㫆㫀㫃㪼㫉㩷㫉㪼㪽㫌㫉㪹㫀㫊㪿㫄㪼㫅㫋㩷㩽㩷㫆㫏㫐㪄㪽㫌㪼㫃㩷㫉㪼㫋㫉㫆㪽㫀㫋㪪㫋㪸㪾㪼㪉䊷㪞㪼㫆㫃㫆㪾㫀㪺㪸㫃㩷㫊㫋㫆㫉㪸㪾㪼㩷㩿䌾㪈㪇㪇㩷㫂㫋㪄㪚㪦㪉㩷㫆㫍㪼㫉㩷㪊㩷㫐㪼㪸㫉㫊㪀㪪㫋㪸㪾㪼㪊䊷㪚㫆㫄㫄㪼㫉㪺㫀㪸㫃㫀㫊㪸㫋㫀㫆㫅Callide A Demonstration Project 㽴Parameter

Callide A Demonstration Project

Vattenfall Pilot-Plant Project

Application

Existing

New installed

Size

30 MWe (㻍100MWt)

30 MWtFuel

Callide coalLignite dustO2 purity

98 r 0.5 %95 % (to be determined)

Flue gas

Mass flow:
140 t/hTemperature:
150 qCCO2:
60 䌾80 %(dry basis)

Mass flow:
14 t/hTemperature:
170 qC
CO2:
80% (dry basis)

Flue gas
treatment

Particulate removal (Existing)Gas drying (Primary)
CO2 liquefaction

Particulate removal
Flue gas desulphurization
Gas drying
CO2 liquefaction

Milestone
Dates

Notice to proceed: Dec. 2007
Practical Completion: Dec. 2008
Shutdown: 2014

Notice to proceed: Nov. 2006
Practical Completion: Aug. 2008
Shutdown: Dec 2011㩿㪍㪀㪪㫋㫌㪻㫐㩷㫆㪽 㪈㪇㪇㪇㪤㪮㪼㩷㪦㫏㫐㪄㪽㫌㪼㫃㩷㪧㪚㪝㪘㫇㫇㫃㫀㪺㪸㫋㫀㫆㫅㩷㫋㫆㩷㪈㪃㪇㪇㪇㪤㪮㪼 㪺㫃㪸㫊㫊㩷㫇㫆㫎㪼㫉㩷㫇㫃㪸㫅㫋㩷㫀㫅㩷㪡㪸㫇㪸㫅㪁㩷㪚㪦㪉 㫉㪼㪺㫆㫍㪼㫉㫐㩷㫉㪸㫋㪼㪑㩷㪐㪌㩼㪁㩷㪚㪦㪉 㫉㪼㪺㫆㫍㪼㫉㩷㫇㫉㪼㫊㫊㫌㫉㪼㪑㩷㪎㪤㪧㪸㪁㩷㪘㫍㪸㫀㫃㪸㪹㫀㫃㫀㫋㫐㪑㩷㪏㪇㩼㪁㩷㪘㫄㫆㫌㫅㫋㩷㫆㪽㩷㪚㪦㪉 㫉㪼㪺㫆㫍㪼㫉㪑㩷㪘㫇㫇㫉㫆㫏㪅㩷㪌㫄㫀㫃㫃㫀㫆㫅㩷㫋㫆㫅㪄㪚㪦㪉㪆㫐㪁㩷㪚㫆㫊㫋㩷㫆㪽㩷㪚㪦㪉 㫊㫋㫆㫉㪸㪾㪼㩷㫀㫊㩷㪼㫏㪺㫃㫌㪻㪼㪻㩷

CO2Compressors (Power)
Air separation units (Power)
O&M
Flue gas ducts etc. 䋨capital䋩
CO2 compressors (Capital)
Air separation units (Capital)

CO2 capture cost(yen/t-CO2)

㪊㪃㪌㪇㪇
㪈㪍㩼

㪊㪃㪇㪇㪇

㪉㪉㩼

㪉㪃㪌㪇㪇
㪉㪃㪇㪇㪇

㪊㩼
Power

Energy

㪌㩼

㪈㪃㪌㪇㪇
㪈㪃㪇㪇㪇
㪌㪇㪇
㪇

㪈㪎㩼
Capital,
O&M

Capital,O&M㪊㪍㩼㪪㫌㫄㫄㪸㫉㫐
Oxy-fuel technology is the candidate of the hopefuland cost-effective CO2 reduction method in the future.
We are going to proceed the development on oxy-fueltechnology
under“Australia-Japan
Callide-A
Demonstration Project”, for environmentally andfriendly pulverized coal fired power plants.
㪘㫊㪿㩷㫉㪼㫄㫆㫍㪸㫃㩷㫊㫐㫊㫋㪼㫄

㪚㫆㪸㫃㪥㪉㪥㫆㫅㪄㪺㫆㫅㪻㪼㫅㫊㪸㪹㫃㪼㩷㪾㪸㫊㪚㪦㪉㩷㫊㫋㫆㫉㪸㪾㪼㩷㪆㩷㫋㫉㪸㫅㫊㫇㫆㫉㫋㪸㫋㫀㫆㫅㪙㫆㫀㫃㪼㫉
㪘㫀㫉䋨㪥㪉䇮㪦㪉䋩㪧㪦㪉㪘㫀㫉㩷㫊㪼㫇㪸㫉㪸㫋㫀㫆㫅㩷
㫌㫅㫀㫋

㪚㪦㪉
㪣㫀㫈㫌㪼㪽㪸㪺㫋㫀㫆㫅㩷㫌㫅㫀㫋㪝㫃㫌㪼㩷㪾㪸㫊㩷㫉㪼㪺㫀㫉㪺㫌㫃㪸㫋㫀㫆㫅㪚㪦㪉㩷㫀㫅㫁㪼㪺㫋㫀㫆㫅㩷㫌㫅㫀㫋㪚㪦㪉㩷㫌㫅㪻㪼㫉㪾㫉㫆㫌㫅㪻㩷㫊㫋㫆㫉㪸㪾㪼

Thank you for your attention䋮

URL: www䋮ihi䋮c䌯䋮j䌰Day 2 Tuesday 16 October 2007
Session 8: FBC/ USC/ IGCC/ CCS

Speech 9 PR China
CFB Technology with Chinese Own Intellectual Property

Mr. Sun Xianbin
Chief Scientist
Chief Engineer
CFB Boiler Technology Department
Thermal Power Research Institute (TPRI)PR China

TPRI

孙献斌
首席研究员,自1988年起在西安热工研究院从事CFB锅炉工程
化的科学研究及应用研究工作，致力于电站级CFB锅炉大型化的研究，负责完成了7项国家及部级攻关项目。
开发设计的首台自主知识产权的国产100MW及210MW CFB锅炉已在分宜发电厂成功投运。作为技术负责人完成的“ 循环
流化床锅炉关键技术研究及应用”获2006年国家科技进步二等
奖，曾获中国电力科学技术一等奖等部级奖4项。在循环流化
床锅炉技术领域获得了4项专利。
目前正在从事我国首台国产330MW CFB锅炉的设计开发及
600MW超临界CFB锅炉前期研究工作。

2007-10-23

1

TPRI

国产CFB锅炉大型化的研究与实践
Research and practice of large domestic
proprietary CFB boilers孙献斌
Sun xianbin
西安热工研究院
Thermal power Research Institute ,P.R.china
15~17 Octerber,2007:Xi’an
2007-10-23

2

TPRI

目 录
contents

1. 技术发展
Technology devolopment
2.大型化关键技术研究
Key Technology Research of Large Capacity
CFB Boilers
3. 国产CFB 锅炉工程示范
Demonstraton of domestic proprietary CFB
boilers
4. 600MW超临界CFB锅炉
600 MW supercritical CFB boiler
5. 应用前景
Application Prospects
2007-10-23

3

1.技术发展
Technology devolopment

•
•
•
•
•
•
•
•
2007-10-23

电站级CFB锅炉的工程应用起步于1996年—引进100MW CFB锅炉
Engineering application of CFB boiler for generating plant wasbegan in 1996 year —improting 100MW CFB bolier
已有9台引进型的300MW CFB 锅炉投入运行
9 units improting technical 300MW CFB boiler have operating
国产CFB锅炉大型化进程较快
Scaling up course of domstic CFB bolier is rapidly
2008年将有国产330MW CFB锅炉投入运行
domstic 330MW CFB boiler will begin to operate in 2008 year
4

TPRI

2. 大型化关键技术研究
Key Technology Research of Large Capacity CFB Boilers• 建立炉膛精确传热计算模型• Exact heat transfer model of furnace has been establisheda1=k×ρ a×t β
b

sus

Rn3

出口区
Rw
Rn2

稀相区

炉
膛
Rn1

过渡区
密相区

2007-10-23

Rn

5

• 建立炉膛高度计算模型
caculation model of furnace heiht has been
establishedHf

Hf=29.7+kf(cb)5045
炉 膛 高 度 H f( m )Hf—炉膛高度,m
furnace heiht ,m
K—炉膛特性系数
furnace characteristic factor
Cb—煤的燃尽指数,
burnout index of coal
—计算模型已经实炉数据验证

40
35
30
25
20
15
10
0

5

10 15 20 25 30 35 40 45 50
燃尽指数 Cb

2007-10-236开发新型外置换热器
Research and developing new type of extenal heatexchanger传统型外置换热器
traditional extenal heatexchanger

2007-10-23紧凑型外置换热器
CHE—Compact ash-flow splitting
and heat exchanger

7

TPRI

4MWthCFB热态试验台-4MWthCFB test facility

针对外置床技术难点—进行了系统的开发研究
research and development of external heat exchanger
has been performed
2007-10-23

8• 建立外置床传热模型
heat transfer model of CHE has been establishedache=λ×tbγ
ache—传热系数,W/(m2℃)
heat transfer coffecient of CHE

λ—传热特性系数, W/(m2℃)
characteristic factor of heat transfer

γ—温度指数temperture index

2007-10-23

以实测数据为基础建立传热模型
Establishing heat transfer model ofCHE based on actual measure datas

9大型化的技术路线
technical route of scaling up

TPRI

两种炉型-Two types in layoutMH和亚洲许多国家一样,中国CFB锅炉大型
化的主要驱动力是燃用劣质燃料和解决
环保问题
The main driving force for thedevelopment of large CFB boiler
technology in China is that it can beused to burn low-grade fuels and tomeet emission standard,as many other
Asian country

2007-10-23

103. 国产CFB 锅炉工程示范
Demonstraton of domestic proprietary CFB boilers
•
•
•
•
•
•

2007-10-23

100MW —330MWCFB锅炉—西安热工研究院和哈尔滨锅炉厂
合作开发研制
100 MW — 330MWCFB Boiler —Research and devlepement by
TPRI and HBC Boiler Works
200MW CFB锅炉— 西安热工研究院和四川锅炉厂
合作开发研制200MWCFB Boiler —Research and devlepement by
TPRI and SC Boiler Works
600 MW CFB锅炉—西安热工研究院已完成概念设计
600 MW CFB Boiler — Concept plan designed by TPRI

11

TPRI

2007-10-23

分宜发电厂100MW CFB 锅炉
100MW CFB Boiler in Fenyi Power Plant

H型整体结构, 2003年6月投运H-shaped layout in configuration, the bolier put into
operation in June 19, 2003
还有该型两台锅炉在越南山洞电厂处于安装阶段
Other this type of two bolier are erectioning in SONDONG
power plant in Vietnam
具有燃用无烟煤的经验

12

良好的运行性能
good operation performance运行值(operation results )ηgl90.76%

SO2

383 mg/Nm3

Ca/S

2.0

NOx

113mg/Nm3

CO

173 mg/Nm3

BMLR

28%BMCR

可用率(availability factor)

≥ 90%

1200

1200
床温

风室温度

1000

1000

800

800

600

600

400

400

200

200

0

风室温度（℃）

参数(parameter)

床温（℃）

TPRI

0
0

1

2

3

4

5

6

7

8

9

10

时间（h)

点火曲线与升负荷
start up and increase load curve
200

1000

床温（℃）

900

150

850
800

100

750
700

2003-01-20，床温变化曲线650

发电功率（MW）

950

50

2003-01-20,升负荷曲线

600
0

50

100

150

200

250

0
300

时间（min)2007-10-2313分宜发电厂210MW CFB 锅炉
210MW CFB Boiler in Fenyi Power Plant带有外置换热器,2006年7月投运
accompanied with External heat exchanger, thebolier put into operation in July,2006.
2007-10-2314煤质特性— coal characteristic
数
名

称

符号

单

位

煤种

设计煤种

值
校核煤种

design coalcheck coal

萍乡上官岭煤

大光山
4.4

Mt

%

4.84

Mad

%

0.88

灰分

Aar

%

49.12

29.56

干燥无灰基挥发分

Vdaf

%

20.25

4.29

碳

Car

%

39.11

62.28

氢

Har

%

1.92

0.43

氧

Oar

%

4.10

1.40

氮

Nar

%

0.65

0.13

硫

Sar

%

0.26

1.8

低位发热量

Qnet.ar

kJ/kg

14000

21570

kcal/kg

3349

5160

水分

变形温度

DT

℃

>1500

1160

软化温度

ST

℃

>1500

1340

熔融温度

FT

℃

>1500

1410

2007-10-23

15

TPRI

外置床内受热面的布置Arrangment of heat surface in CHE• 210 MW CFB锅炉配有4台外置床,其内布置高
温低温过热器和高温再热器backpass

SHI

RHⅡ
furnace

RHⅡ

2007-10-23

SHI• 210MW CFB boiler isequipped with 4 CHEs,
inside which part ofsuperheater andreheater are arranged.

16

TPRI
锅炉运行数据—Boiler operation data
内江100MW分宜100MW分宜210MW1000

床温( ℃)

950
900
850
800
750
700
0

10 20 30 40 50 60 70 80 90 100 110 120
锅炉负荷( %)

锅炉最大连续出力:690t/h (224MW)
Boiler Maximum continuous rating: 690t/h (224MW)
CHE的调节作用使床温在较宽负荷范围内维持最佳燃烧温度optimum bed
temperature within wide load range by CHE adjusting
2007-10-23

17

D

1.5W

2.5W

炉膛模块式放大—充分利用已有工程经验的放大方法
Modular furnace design — the Scaling up method of
sufficient use existing experiences

W

100MW CFBB

2007-10-23

1.25W

210MW CFBB

1.3D

330MW CFBB

18

分宜发电厂330MW CFB 锅炉正在安装阶段
330MW CFB boiler is erectioning in Fenyi Power Plant•330MW CFB锅炉预计2008年10月投运;•330MW CFB bolier will put into operation in October,2008;•中国最大容量的CFB锅炉•The largest capacity CFB bolier in china
2007-10-23

19

进度安排
project scheduling
2006

2007

2008

1 2 3 4 5 6 7 8 9 10 11 12 1 2 3 4 5 6 7 8 9 10 11 12 1 2 3 4 5 6 7 8 9 10 11 12
性能设计
详细设计
制造与安装
调试
运行

2007-10-2320

正在设计的M型300MW CFB锅炉
M-shaped 300MW CFB Boiler designing

二次风
出口
一次风
出口

风- 水联合
冷渣器

一次风接口
启动燃烧器

M型CFB锅炉具有钢耗量小、给煤系统简单等优点，可作为燃用烟煤、褐煤的首选炉型.
CFB boiler of M-shaped layout is less metal
consumption,and its coal feeding system simpler. It is first
choice of layout for bituminious coal and lignite
2007-10-23

21

TPRI

4.600MW 超临界 CFB 锅炉
600MW supercritical CFB boiler– CFB锅炉技术发展的必然趋势
development trending of CFB technology– 可同时实现高效发电和清洁燃烧,代表了现代电站锅炉发展的先进的技术.
– the 600 MW supercritical CFB boiler will be the development trendingof CFB technology since it will generate power in a way of clean
combustion and with higher efficiency at the same time. The
supercritical CFB boiler will combine the advantages of CFB boiler
and supercritical boiler, thus it will be one of the most advanced
technologies in modern power plants

2007-10-2322超临界 CFB 锅炉热流密度与PC炉的比较Comparison of heat flux density between CFB boiler and PC boiler

•
•

•

•
•

CFB锅炉炉内燃烧温度较低且沿炉高分布均一炉内热流密度
低于煤粉炉;a lower furnace combustion temperature
with a uniform profile and a lower heat flux to watercooled tubes compared to the pulverized coal boilers.
热流密度较高区域对应于工质最低的炉膛下部;the water wall area with a relatively higher heat flux iscorresponding to the lower part of the furnace with thelowest working medium temperature
因此水冷壁管内出现膜态沸腾（DNB）和蒸干（DRO）现象
的可能性大为减小;therefore the possibility of heattransfer deterioration inside the water wall tubes will be
reduced and then a lower specific mass flow rate canbe used
水冷壁采用垂直内螺纹管屏, 直管水冷壁可防止炉内下降边壁
流的磨损
The water walls of supercritical CFB boiler can be made byvertical ribbed tubes, which is favorable to prevent theheavy erosion of the water wall due to the down streaming
solids flow near the water wall

2007-10-23

40

CFB Boiler
PC Boiler

35

Furnace height H(m)

•

30
25
20
15
10
5
0
0

100

200

300

400

500

Heat flux density （KW/m2)

23

超临界 CFB 锅炉技术难点
technical difficulty point of supercritical CFB boiler• 超出经验范围的炉膛高度以上
区域的气固浓度及传热特别;• 横向热流密度分布;• 分离器气固分配均匀性;• 特殊工况下的水冷壁传热恶化问题;• 事故状态下的锅炉的安全性;

2007-10-2324

600 MW CFB 锅炉概念设计
Concept plan Of 600 MW CFB Boiler•H型布置;•H-shaped layout in configuration.
•紧凑式分流回灰换热器;•Compact ash-flow splitting and heatexchanger•6个旋风分离器•6 cyclones•垂直管屏水冷壁•6 cyclones•裤衩式炉膛
•Pent-legs furnace
TPRI

2007-10-23

25

5. 应用前景—特别适用于劣质燃料的清洁煤发电技术
Application Prospects —Clean coal generation
technology especially applicable for low-grade fuel•••

通过十年的技术发展,中国已能够采用大型CFB锅炉技术清洁地发电, 该项技术特别适合于经济不断增长而又需要同时解决好环保问题的亚洲国家.
developing CFB technology through ten years, China can use large
CFB bolier technology to clean generate electricity.CFB boiler is
especial suitable for Asian country .
大型CFB锅炉能够经济的达到SO2及NOx排放控制要求,可作为首选技术推广应用 (Sarzs≤1.0 g/MJ的中低硫煤)•

burning low or medium sulfur coal (Seq<1.0 g/MJ)•

具有燃烧劣质煤的特点,可燃用洗中煤,煤矸石及煤泥等•

burning coal wash by-products•

CFB锅炉能更好的燃用煤粉锅炉难以燃烧的难燃煤种,如易结渣煤种.

•

burning anthracite with a low volatile content, for example burningslagging coals

2007-10-23

26

TPRI

THANK YOU!

If you have any questions about thispresentation,please feel free to contact
Thermal Power Research Institute
136 Xing Qing Road, 710032
Xi’an, P. R. China
Tel: +86-29-82102325
Fax: +86-29-83238818
E-mail: sunxianbin@tpri.com.cn

2007-10-23

27

Day 2 Tuesday 16 October 2007
Session 8: FBC/ USC/ IGCC/ CCS

Speech 10 PR China
Study and Application of Dissimilar Metal Welding of T91-F12 Steels

Mr. Ren Ping
Shanghai Shidongkou Second Power Plant
PR China任平华能上海石洞口第二电厂主任、高级工程师
1978.7-1982.7毕业于山东工学院、学士学位、高级工程师；
82.8-88.9安徽电力修造厂 生技科： 焊接专职工程师；
88.9-90.9上海电力安装第一工程公司 施工技术科：焊接及金属监督专职工程师；90.9-92.6华能上海分公司 质监部：材料及焊接专工分公司金属监督专工；
92.6-95.8华能上海石洞口第二电厂 检修部：电厂金属监督专工；95.8-2002.5华能上海石洞口第二电厂 检修部：部门技术主管；
2002.5-今 华能上海石洞口第二电厂 检修部：副主任、主任；
扩建办公室：主任。
主要从事的研究：
金属材料及焊接、电厂状态检修及优化管理等。
主要获得的荣誉：1、华能上海石洞口第二电厂1号汽轮机调节级叶片损坏原因分析2、超临界600MW锅炉再热器系统超温改造

部科技二等奖；市局科技一等奖；

3、2004-2005年度华能国际电力股份有限公司技术专家（金属材料及焊接专业）以及2006-2007年
度华能国际电力股份有限公司技术专家（金属材料及焊接专业），并任两届专家组组长

T91-F12异种钢管焊接工艺研究及生产应用Study and Application of T91-F12
Heterogeneous Steel Tube Welding
Procedure
任 平等
2007.9.19

【摘要】T91和F12是两种不同标准系列的马氏体耐热钢，极少在同一场
合使用。根据国内外在实施T91、X20CrMoV121这两种材料的同种钢钢管焊接工艺的研究与应用经验，确定了16套焊接工艺方案进行T91和F12钢管之间的焊接工艺研究。

【Abstract】F12 and T91 are martensitic heat-resistant steels of two
different standard, and they are rarely used in the same situation.
Based on the domestic and overseas research and application
experiences in welding procedure of homogeneous steel tubes with
T91 and X20CrMoV121 materials, 16 welding schemes have been
determined to carry out the study on welding of T91 and F12 steel
tubes.



对这些不同焊接参数和工艺条件下的焊接接头解剖进行各项理化性能试
验，理化性能试验包括X射线探伤、金相组织、室温及565℃高温短时拉
伸试验、硬度试验、断口试验、面弯和背弯弯曲试验以及最佳工艺条件
下的高温短时持久性能的复核试验等。

Various physical and chemical performance tests are carried out on thewelded-joint dissections with different parameters and conditions,
including X-ray flaw detection, metallurgical microstructure, short time
tensile test at room temperature and 565℃, hardness test, fracture
test and bend test of face-bending and back-bending, and short timeendurance recheck test at high temperature in optimal condition, etc.

确定了F12和T91钢种最佳的焊接工艺方案：焊前不低于50℃预热，采用GTAW（2层）＋SMAW焊接方法，焊接材料分别采用MTS3焊丝（Φ2.4）以及9MV-N
焊条（Φ2.5），焊后24小时内采用730℃～760℃保温1小时的回火处理工艺。
并且在再热器换管改造工程中得以成功应用。

Then the optimal welding procedure of F12 and T91 is as follow: preheating
not under 50℃ before weld, with GTAW (2 layer) +SMAW method and MTS3
wire(Φ2.4) and 9MV-N electrode(Φ2.5) materials, and holding at
730℃~760℃ for one hour's tempering in 24 hours after weld. It is
successfully applied in the modification of reheater pipes.



1. 前言



F12(X20CrMoV121)钢是德国12%Cr型马氏体热强钢。该钢具有较高的抗氧化性能，组
织稳定性良好，主要用于壁温540～560℃的集箱、蒸汽管道，以及壁温达610℃的过热
器和壁温达650℃的再热器，但该钢焊接性能较差，若焊接预热温度低，冷却速度过
快，极易在接头中产生焊接冷裂纹，故一般要求有较高的预热温度，但预热温度也不能过高，否则会导致接头的塑韧性下降。在我国80～90年代投产的发电机组中均有大量使用。



1. ForewordF12 (X20CrMoV121) steel is German 12% Crmartensitic refractory steel. It has highantioxidant ability and good structure stability, mainly used in headers and steam
pipes with surface temperature at 540~560℃, superheaters at 610℃ and reheaters at
650℃. But it doesn’t have wonderful welding properties. If the preheating
temperature is low and cooling speed is too fast, it’s easy to create welding cold crack
at the joint. So high preheating temperature is generally required. but thetemperature can’t be too high, or it will cause the decreasing in plasticity andtoughness. It was widely used in generating sets commissioned in 1980’s to 1990’s in
our country.



而T91钢系改进型的9％Cr高强度马氏体耐热钢，该钢不仅具有高的抗氧化性能和抗高温蒸汽腐蚀性能，而且还具有良好的冲击韧性和稳定的持久塑性及热强性能。主要主要用于壁温≤625℃的高温过热器、壁温≤650℃的高温再热器钢管，以及壁温≤600℃的高温集箱
和蒸汽管道，国内外已逐步用该钢代替T22、F12、TP304L、TP347H等，但该钢焊接性能也比较差，容易产生焊接冷裂纹，所以同样要求有合适的预热温度和及时进行焊后回火处理。
As the improved type of T91 steel, 9%Cr high strength martensitic heatresistant steel has not only high antioxidant ability and hot corrosion
resistance, but also good impact toughness and steady enduring plasticity
and thermal intensity characteristic. It’s mainly used in steel tubes of hightemperature superheaters with surface temperature≤625℃ and hightemperature reheaters with surface temperature≤650℃, and hightemperature headers and steam pipes with surface temperature≤600℃. It
has taken the place of T22, F12, TP304L, and TP347H stage by stage at home
and abroad. But it also has short welding properties and is easy to create
welding cold crack. So it’s also required proper reheating temperature andtimely tempering after weld.

华能上海石洞口第二电厂有2台600MW超临界机组，92年投产，锅炉中高温过热器、高温
再热器、后屏过热器等受热面管子和集箱均大量使用F12材料，因已连续运行了10万小时
以上，且运行中存在超温的情况，部分受热面的材料性能已有明显下降，严重威胁锅炉的安全运行，所以部分管段将进行更换。同时由于F12钢产量逐步减少，采购渠道的限制，
价格的快速上涨，经研究决定使用T91代替原F12管材的部分管段，所以必须试验确定T91F12异种钢焊接工艺。
Huaneng Shanghai Shidongkou Second Power Plant has two 600MW supercritical units,
which were commissioned in 1992. F12 material is largely used in the pipes and headersof the heating surfaces such as high temperature superheaters, high temperature
reheaters and rear platen reheaters of boiler. Since the units have operated continuously
for more than 10 hundred thousand hours and there are over-temperature situations inoperation, the performance of material at some heating surfaces is obviously degradedand seriously threatens the safety of boiler operation. So some pipe segments have to
be changed. Meanwhile, since the decreasing yield of F12 steel, the limit in purchasing
channel and rapidly increasing in price, T91 is determined to be instead of F12 in somepipe segments after serious research. So it is necessary to do tests to confirm thewelding procedure of T91-F12 heterogeneous steels.



2．焊接材料的选择与研究焊接F12和T91钢难度较大，当焊接线能量过大时，会引起组织过热，粗大晶粒从而使焊缝的脆性大大增加，塑韧性不稳定。而当焊接线能量过小时，则易于产生各种焊接冷裂纹。
所以要合理选择焊接工艺、焊接规范、预热和焊后热处理温度。同样焊接材料也是影响焊
接接头工艺性能和力学性能的重要因素，必须正确选择。



2. Selection and Research of Welding Materials

It’s difficult to weld F12 and T91 steels. When the linear energy is too big, it will cause
the structure over heat, and the coarse grains, increasing the brittleness of welding
seams and leading the instability in plasticity and toughness. While the linear energy is
too small, it will be easy to create all kinds of welding cold cracks. So the welding
procedure, welding standard, the temperature of preheating and After-weld Heat
treatment should be rationally selected. Welding material is also an important factor
affecting the performances and mechanical properties of welded-joint, and has to becorrectly selected also.



根据国内外在实施T91、X20CrMoV121这两种材料的同种钢钢管焊接工艺的研究与应用经验，确定对应用于不同焊接方法（GTAW、SMAW）的焊接材料，列于
表1。进行T91与X20CrMoV121焊接工艺研究与评定用的钢管为：T91管子为日
本进口的钢管，规格为Φ63.5×6.5，X20CrMoV121管子为德国进口的钢管，规格为Φ63.5×6.3，两种钢管的化学成分见表2。

Based on the domestic and overseas research and application experiences in
welding procedure of homogeneous steel tubes with T91 and X20CrMoV121
materials, welding materials applied in different welding methods (GTAW and
SMAW) have been determined, as listed in Tab.1.The steel tubes used inresearch and qualification of welding procedure of T91 and X20CrMoV121
are: T91 steel tubes imported from Japan, Φ63.5×6.5, and X20CrMoV121
steel tubes imported from Germany, Φ63.5×6.3. The chemical components ofthese two materials are showed in Tab.2.



表1、T91－F12(X20CrMoV121)异种钢焊接用焊接材料一览表
材料牌号

C

Mn

Si

S

P

Cr

Ni

Mo

V

Nb

N

MTS3(Φ2.4)
焊丝

0.115

0.54

0.25

0.001

0.006

8.78

0.69

0.98

0.2

0.04

0.058

9MV-N(Φ2.5)
焊条

0.08

0.61

0.20

0.007

0.008

9.00

0.70

1.00

0.18

0.03

0.04

CROMOTIERME
12(Φ2.5)焊条

0.195

0.5

0.19

0.01

0.023

11.2

0.64

1.05

0.2

CROMOTIERME
12(Φ2.5)焊丝

0.195

0.5

0.19

0.01

0.023

11.2

0.64

1.05

0.2



表2、T91－F12(X20CrMoV121)异种钢焊接研究用原材料一览表

材料牌号

C

Mn

Si

S

P

Cr

Ni

Mo

V

T91

0.09

0.39

0.26

0.002

0.015

8.19

0.16

0.92

0.2

X20CrMoV121

0.18

0.60

0.27

0.002

0.019

10.42

0.63

0.89

0.26

上述钢管的化学成分符合相关标准的要求。



3．焊接性试验和热处理规范选择

3.1焊接方法和焊接工艺参数的选择对T91和F12马氏体耐热不锈钢类型的钢管的焊接，通常采用的焊接方法为钨极氩弧焊或者为钨极氩弧焊打底＋手工电弧焊的工艺。由于这两种材料的含碳量比较高，可焊性比较
差，所以上述两种方法均应采用在预热的条件下进行焊接，而且焊后还应及时进行回火处理。因此，合适的预热温度以及焊后回火温度的研究，也是保证焊接质量的重要一环。
根据分析结果，选择的焊接工艺研究方案如表3。



3. Weldability Test and Selection of Heat Treatment Standard

3.1 Selection of Welding Method and Welding Procedure Parameters
Usually the welding method we use in T91 and F12 martensitic heat-resistant stainlesssteel tubes is argon tungsten arc weld or argon tungsten arc weld scratch coat+manualarc weld. Since these two materials both have high carbon content, they don’t have good
weldability. So they have to be preheated before welding and tempered after welding in
the above two methods. Therefore, research of proper temperature in preheating andtempering is also an important step to ensure the quality of welding.
Selected welding procedure based on the result of the research is showed as Tab.3.



3.2焊接接头的各项理化性能试验

在确定了上述各项工艺方案以及各工艺条件下的焊接参数以后，据此对T91和
F12钢管之间的焊接。每种工艺共完成了6只焊接接头，然后对这些焊接接头解剖进行各项理化性能试验，理化性能试验包括X射线探伤、金相组织、室温及565℃高温短时拉伸试验、硬度试验、断口试验、面弯和背弯弯曲试验以及最佳
工艺条件下的高温短时持久性能的复核试验等。



3.2 Various Physical and Chemical Performance Tests on Welded-joint
After determining all the above procedure schemes and welding parameters in various
procedure conditions, the welding of T91 and F12 steel tubes was carried out. Eachprocedure accomplished 6 joints and then various physical and chemical performance
tests were carried out on the welded-joint dissections, including X-ray flaw detection,
metallurgical microstructure, short time tensile test at room temperature and 565℃,
hardness test, fracture test and bend test of face-bending and back-bending, and shorttime endurance recheck test at high temperature in optimal condition, etc.



表3：T91－F12管对接焊工艺方案：预热温度（℃）焊接工艺焊接材料牌号焊后热处理温度（℃）

MTS3焊丝（Φ2.4）
氩弧焊
CROMOTIERME12焊丝（Φ2.4）
50

MTS3焊丝（Φ2.4）＋9MV-N（Φ2.5）
氩弧焊打底＋
手工电弧焊

730,760
保温时间均为1小时

CROMOTIERME12焊丝（Φ2.4）＋
CROMOTIERME12焊条（Φ2.5）
MTS3焊丝（Φ2.4）

氩弧焊
CROMOTIERME12焊丝（Φ2.4）
120

MTS3焊丝（Φ2.4）＋9MV-N（Φ2.5）
氩弧焊打底＋
手工电弧焊

CROMOTIERME12焊丝（Φ2.4）＋
CROMOTIERME12焊条（Φ2.5）

730,760
保温时间均为1小时

4．试验结果分析

4.1 焊接接头的射线探伤对全部16种焊接工艺条件下的96只焊接接头，分别按DL/T821-2002标准
中进行了射线探伤，探伤结果表明96只焊接接头均符合DL/T821-2002标
准中规定的Ⅱ级要求。



4．Analysis on Test Result

4.1 Ray Flaw Detection of Welded-joint

Ray flaw detection according to DL/T821-2002 Standard was carried out on 96
joints welded in 16 welding procedures. And the result shows that 96 joints allmeasured up the Class Ⅱ requirement of DL/T821-2002 Standard.



4.2 焊接接头的金相组织试验对全部16种焊接工艺条件下的焊接接头，均进行了金相组织检验。

从金相组织试验研究结果表明，T91－F12分别按表3各项工艺及其焊接参数条件
下的焊缝金相组织均为保持马氏体位向的回火索氏体组织，未在组织中发现淬火
组织以及其他过烧组织，位于T91以及F12热影响区以及熔合线附近的组织形貌
也基本正常。



4.2 Metallurgical Microstructure Test of Welded-joint

Metallurgical microstructure test was carried out on all joints welded in 16 welding
procedures.

The result shows that the welding seam metallurgical microstructures of T91-F12 weldedin the condition of the procedures and parameters in Tab.3 are all tempering sorbitic
structure that keeps martensitic orientation. Quenching structure or other over-burning
structures are not found in the microstructure. The structure forms near the heataffected zone of T91 and F12 and the fusion line are also natural.

同一种工艺条件下，50℃预热温度与120℃预热温度的各区域间的金相组织无明
显差别；在其他工艺参数相同的条件下，焊后730℃回火处理的焊缝组织中的铁
素体板条比760℃回火处理的焊缝组织中的铁素体板条稍粗，但没有明显的差异。
因此，通过对T91－F12全部16种焊接工艺条件下的金相组织检验，从焊接接头的金相组织角度而言，这16种焊接工艺及其相关参数均可予以应用。

In the same procedure, the metallurgical microstructures of each zone have no
big differences between preheating at 50℃ and 120℃. And in the same
conditions of different procedures, the ferritic laths in the welding seam
structure which was tempered at 730℃ after weld is a little bit thicker thanthose tempered at 760℃, but the difference is not obvious. So according to
the metallurgical microstructure of the welded-joint by metallurgicalmicrostructure test of the all 16 kinds of T91-F12 welding procedures, all theseprocedures and their parameters can be put into application.



4.3 焊接接头的室温及565℃高温短时拉伸试验

对全部16种焊接工艺条件下的焊接接头，均进行了室温和565℃高温短时拉伸试验。室温
和565℃高温短时拉伸试验按DL/T868-2004《焊接工艺评定规程》取样与加工Bo＝10mm
试样，试验方法为：室温拉伸试验按GB/T2651《焊接接头拉伸试验方法》、GB/T228－
2002《金属材料室温拉伸试验方法》，高温短时拉伸按GB/T43338-1995《金属材料高温拉伸试验方法》在AMSLER液压式万能材料试验机上进行试验。



4.3 Short Time Tensile Test at Room Temperature and 565℃ of Welded-jointShort time tensile test at room temperature and 565℃ was carried out on all weldedjoints in 16 welding procedures. This test was sampled and machining to Bo=10mm
pattern according to DL/T868-2004 ”Regulations of Welding Procedure Qualification”.
The method of test is as follow: tensile test at room temperature is according to the
GB/T2651 ”Methods of Tensile Test for Welded-joint” and GB/T228-2002 “Methods ofTensile Test for Metal Materials at Room Temperature”, and short time tensile test at
high temperature tested on the AMSLER hydraulic test-bed for all materials according to
GB/T43338-1995 “Methods of Tensile Test for Metal Materials at High Temperature”.



室温和565℃高温短时拉伸试验研究结果表明，T91－F12分
别按表4各项工艺及其焊接参数条件下的焊缝室温和565℃高温短时拉伸试验基本均符合相关规定的要求，并且所有试样
均断裂在F12母材侧。

The result of the test shows that the welding
seams of T91-F12 welded in procedures andparameters listed in Tab.4 all meet thecorresponding requirements and all samples
rupture at F12 side.



4.4焊接接头的硬度试验对全部16种焊接工艺条件下的焊接接头，均分别进行了母材、热影响区、
焊缝的硬度试验，硬度试验是按DL/T868-2004《焊接工艺评定规程》取样，并按GB2654－89《焊接接头及堆焊金属硬度试验方法》以及GB231《金属布氏硬度试验方法》，在69－I型布洛维硬度试验机上进行试验。



4.4 Hardness Test of Welded-jointBase material, heat affected zone, and welding seam hardness were tested on
all welded-joints welded in 16 procedures conditions. The hardness test
sampled according to DL/T868-2004 ”Regulations of Welding Procedure
Qualification” and tested on 69-I BRV hardness test-bed according to GB2654－89 “Methods of Hardness Test of Welded-joint and Surfacing Metal” andGB231 “Methods of Metal Brinell Hardness”.



硬度试验（HBS）试验研究统计结果详见表4，结果表明，T91－F12分
别按表3各项工艺及其焊接参数条件下的母材、热影响区、焊缝的硬度基
本均符合相关规定的要求。



表4中同时列出了当焊缝采用GTAW+SMAW焊接工艺条件下的各项硬度
测量结果。



The detailed result statistical of the hardness test（HBS）is listed in
Tab.4. It shows that the base material, heat affected zone and welding
seam hardness of T91-F12 welded with different procedures andparameters listed in Tab.3 all meet the standard requirements on thewhole.



Various hardness measurements of the welding seams by
GTAW+SMAW procedure are also listed in Tab.4.



4.5 面弯和背弯弯曲试验

对全部16种焊接工艺条件下的焊接接头，均分别进行面弯和背弯弯曲试验。

弯曲试验是按DL/T868-2004《焊接工艺评定规程》取样，并按GB2653《焊接接头弯曲及压扁试验法》，在WE-60液压式万能材料试验机上进行试验。试验结果
表明所有全部16种焊接工艺条件下的焊接接头的面弯和背弯，均合格。



4.5 Bend Test of Face-bending and Back-bending
Bend test of face-bending and back-bending was carried out on all weldedjoints welded in 16 procedures.
Bend test is according to DL/T868-2004 ”Regulations of Welding Procedure
Qualification” and tested on WE-60 hydraulic test-bed for all materials
according to GB2653 “Method of Bend and StaveTest of Welded-joints”. The
result of the test shows that all face-bending and back-bending of the weldedjoints welded in 16 procedures are eligible.



表4、T91－X20CrMoV121各工艺条件下的母材、热影响区、焊缝的硬度（HBS）
试样号

F12母材

F12热影响区

焊缝

T91热影响区

T91母材

平均值

250

256

285

238

221

最大值

297

300

378

345

270

最小值

234

229

236

203

199

1315

235

252

263

241

211

1321

242

247

263

210

208

1415

278

282

307

265

245

1424

247

291

296

237

215

1711

239

244

272

236

212

1724

236

238

236

203

209

1812

297

300

378

345

270

1821

243

229

266

210

206



5.各项性能的分析讨论与最佳焊接工艺的确定

根据T91－F12分别按表3各项工艺及其焊接参数条件下各项理化性能试验包括X
射线探伤、金相组织、室温及565℃高温短时拉伸试验、硬度试验以及断口试验
研究结果，T91－F12分别按3各项工艺及其焊接参数条件下的X射线探伤、金相组织、室温及565℃高温短时拉伸试验均无明显的差别，但硬度试验结果表明了
不同的焊接工艺对热影响区以及焊缝硬度还是有一定影响的。



5. Analysis and Discussion of Various Performances and Determiningof Optimal Welding Procedure
According to the result of various physical and chemical performance tests of
T91-F12 welded in all procedures and parameters in Tab.3, there’s no obvious
difference in X-ray flaw detection, metallurgical microstructure and short time
tensile test at room temperature and 565℃ with different procedures andparameters. But the result of hardness test shows that different procedures dohave impact on heat affected zone and welding seam hardness.



5.1最佳焊接工艺综合分析结果并考虑了现场焊接工况与条件，我们选择具有良好性能匹配并便于现场施焊的工艺为：焊前不低于50℃预热，采用GTAW（2层）＋SMAW焊接方法，焊接材料分别采
用MTS3焊丝（Φ2.4）以及9MV-N焊条（Φ2.5），焊后24小时内采用730℃～
760℃保温1小时的回火处理工艺。



5.1 Optimal Welding ProcedureGenerally analyzing the result and considering the welding conditions on
worksite, the procedure we choose that has proper performances and is easy
to use on the worksite is as follow:

Preheating not under 50℃ before weld, using GTAW (2 layer) +SMAW method
and MTS3 wire(Φ2.4) and 9MV-N electrode(Φ2.5) materials, and holding at
730℃~760℃ for one hour's tempering in 24 hours after weld.



5.2最佳焊接工艺条件下的高温短时持久性能的复核试验

在对T91－F12分别按表3各项工艺及其焊接参数条件下各项理化性能试验包括X射线探伤、金相组织、室温及565℃高温短时拉伸试验、硬度试验以及断口试验研究的基础上，得出了针对T91－F12小口径管对接焊的
最佳工艺：



5.2 Short time Endurance Recheck Test at High Temperature
in Optimal Condition

Based on the various physical and chemical performance tests
including X-ray flaw detection, metallurgical microstructure, short time
tensile test at room temperature and 565℃, hardness test and fracture
test of T91-F12 welded in all procedures and parameters in Tab.3,即焊前不低于50℃预热，采用GTAW（2层）＋SMAW焊接方法，焊接材
料分别采用MTS3焊丝（Φ2.4）以及9MV-N焊条（Φ2.5），焊后24小时
内采用730℃～760℃保温1小时的回火处理工艺，依据这一结论，对该工艺条件下的焊接接头取样进行了565℃温度下的短时持久性能的复核试验。
optimal welding procedure of small diameter pipe butt welding is
obtained, i.e. preheating not under 50℃ before weld, using GTAW (2layer) +SMAW method and MTS3 wire(Φ2.4) and 9MV-N
electrode(Φ2.5) materials, and holding at 730℃~760℃ for one hour's
tempering in 24 hours after weld. According to the above conclusion,short time endurance recheck test at 565℃ was carried out on thesamples welded in this condition.



T91－F12焊接接头565℃温度下的短时持久性能选择的试验
参数是参照相关标准和资料中的进口材料的高温持久长时数据，通过Lason-Miller参数法进行数据处理后确定的，处理结果详见图1。

The parameters of short time endurance test at 565℃ of
T91-F12 refer to the data of import materials endurance athigh temperature in corresponding standards, and aredetermined after data processing by Lason-Miller
parameter method. The result of processing is viewed in
Fig.1.



依据图1，对T91－F12焊接接头565℃温度下的短时持久性能500小时考核试验的图示应力值应为240MPa，按照持久强度试验数据的±20％的分散度，取500
小时考核试验应力值为192MPa。T91－X20CrMoV121焊接接头565℃、500小时短时持久考核试验试验结果见表5，试验结果表明，两种工艺条件下的焊接接头
565℃温度下的短时持久性能，500小时的持久断裂应力均高于192MPa，结果符
合要求。

As showed in Fig.1, the diagrammed stress of short time endurance test for
500 hours at 565℃ on welded-joint of T91-F12 is 240MPa. Considering thedispersity of ±20％, stress of check test for 500 hours is 192MPa. The resultof short time endurance test for 500 hours at 565℃ on T91-X20CrMoV121
welded-joints is showed in Tab.5. The result shows that the short timeendurance stress of welded-joints with two procedures at 565℃ for 500 hours
both above 192MPa, and meet the requirement.



表5、T91－F12焊接接头565℃、500小时短时持久考核试验结果焊接工艺描述

试验温度
℃

持久应力
（MPa）

试验结果

50℃预热，GTAW＋SMAW，MTS3焊丝（Φ2.4）＋
9MV-N焊条（Φ2.5），730℃回火

565

192

562小时未断

50℃预热，GTAW＋SMAW，MTS3焊丝（Φ2.4）＋
9MV-N焊条（Φ2.5），760回火

565

192

562小时未断

T91-X20CrM oV121 持久强度 L-M 曲线应力 (MPa)

1000

100

X20CrM oV121 持久曲线，注 1
T91持久曲线，注 2

10
20

21

22

23

24

25

26

27

28

L-M 参数

图1、T91与F12 (X20CrMoV121)管子材料持久强度材料曲线
注1：数据取自DIN17175
注2：数据取自日本NKK－锅炉用钢管技术交流会议资料

29

6.焊接工艺评定



在焊接工艺研究的基础上，根据DL/T868-2004《焊接工艺评定规程》对其进行了焊接工艺评定。



6.1试验条件试验材料：T91, F12(X20CrMoV121)；

材料规格：Ф63.5×6.3 Ф63.5×6.3；

试样状态：水平、垂直定位，≥50℃预热，GTAW＋SMAW，730～760℃焊后热处理；

接头形式：对接焊焊接接头。



6. Welding Procedure Qualification

Based on the research and according to DL/T868-2004 ”Regulations of Welding Procedure
Qualification”, welding procedure qualification is carried out.



6.1 Test ConditionMaterial: T91, F12 (X20CrMoV121)

Specification: Ф63.5×6.3, Ф63.5×6.3

Status: horizontal and vertical fixed welding, preheating ≥ 50℃, GTAW+SMAW, 730～760℃ afterweld heat treatment

Sample: welded-joint of butt welding

6.2焊接工艺参数

水平固定与垂直固定焊均采用双V型坡口，焊接工艺参数如下：焊前不低于50℃预热，采用GTAW（2层）＋SMAW焊接方法，焊接材料分别采用MTS3焊丝（Φ2.4）以及9MV-N焊条（Φ2.5），焊后24小时内
采用750±10℃保温1小时的回火处理工艺。



6.2 Welding Procedure ParametersHorizontal and vertical fixed welding both used double V groove. The
procedure parameters are as follow:

Preheating not under 50℃ before weld, with GTAW (2 layer) +SMAW
method and MTS3 wire(Φ2.4) and 9MV-N electrode(Φ2.5) materials,
and holding at 750±10℃ for one hour's tempering in 24 hours after
weld.



6.3试验校核对水平、垂直对接全位置焊接接头，按DL/T868-2004《焊接工艺评定规程》要求，均进行了相关试验校核。 符合要求。

6.3 Tests

Corresponding tests were carried out on horizontal andvertical butt welded-joints according to DL/T8682004 ”Regulations of Welding Procedure Qualification” andthey all meet the requirement.

焊后热处理工艺曲线（Curve of after-weld heat treatment procedure）:℃

750℃±10℃（恒温1小时）

300℃



7.生产应用

2007年3月#1锅炉高温再热器的10CrMo910段受热面管子进行更换升级，采用T91管材代
替原材料性能已严重恶化的10CrMo910管段。在高再改造现场施工过程中共有495只
T91+F12的异种钢焊口采用了该评定所确定的焊接施工工艺和焊后热处理工艺。施工过程
中焊口的硬度、金相组织和射线探伤检验均合格，硬度值和组织形貌与工艺评定中一样。
目前，改造后的锅炉受热面安全运行。证明了采用该评定的T91+F12异种钢焊接工艺在性
能和工艺等方面是能够满足实际应用的。



7. Application in producing
Part of the heating surfaces of Unit 1 boiler high temperature reheaters which are madeof 10CrMo910 were changed on March of 2007. T91 material was used to take the placeof 10CrMo910 where the original material performance has badly deteriorated. 495
T91+F12 heterogeneous steel weld bonds on the worksite of modification on hightemperature reheaters used the welding and after-weld heat treatment procedures,
which have been determined by the qualification. The weld bond hardness, metallurgicalmicrostructure and ray flaw detection during construction were all eligible. The hardness
measurement and structure forms well met the qualification. The modified heating
surfaces are in safe operation at present, which proves that the qualified T91+F12
heterogeneous steel welding procedure can meet the performances and techniques inapplication.



8.结论



8.1T91-F12异种钢焊接性能差，焊接时必须控制线能量，焊前需预热，并控制不小于50℃最为合适。焊后为改善焊接接头性能，建议采用750±10℃温度进行焊后热处理。

8.2根据所评定的焊接工艺进行焊接，华能上海石洞口第二电厂高温再热器出口段管子更换焊口经检查均符合要求。所研究评定的焊接工艺能满足技术标准和生产应用要求。

8. Conclusion



8.1 T91-F12 heterogeneous steel is short in weldability, so the linear energy must be
controlled while welding and preheating must be carried out before weld with proper
temperature not under 50℃. In order to improve the performances of joints, after-weldheat treatment at 750±10℃ is recommended.



8.2 The weld bonds of changed outlet pipes of Huaneng Shanhai Shidongkou Second
Power Plant high temperature reheaters which were welded with the qualified
procedures all meet the requirements. And the researched and qualified procedures canmeet the technical standard and application requirements.

谢谢！请多指导！

Day 3 Wednesday 17 October 2007

Session 9:
Flue Gas Cleaning Technology

Day 3 Wednesday 17 October 2007
Session 9: Flue Gas Cleaning Technology

Speech 1 PR China
Study of Application Issues of SCR
on Chinese Coal Fired Utility Boilers

Mr. Wang Yueming
Assistant President
Thermal Power Research Institute (TPRI)
Director
National Engineering Research Center for Clean Coal Combustion (NERC)PR China

TPRI
中国燃煤电站锅炉SCR技术应用问题探讨Study of Application Issues of SCR
on Chinese Coal Fired Utility Boilers
王 月 明
Mr. Wang Yueming
西安热工研究院有限公司
Thermal Power Research Institute电站锅炉煤清洁燃烧国家工程研究中心
National Engineering Research Center for
Clean Coal Combustion for Utility Boilers
2007-10-17 · 西安 Xi’an

TPRI

主 要 内 容Contents

1.国内SCR技术的应用现状
Current Application Situation in China
2.煤质和锅炉特点对SCR催化剂的影响Influences of Coal Property and Boiler Type on SCR Catalyst
3. 中国动力用煤与炉型特点
Properties of Chinese Steam Coals
4. 工程实例介绍
Industrial Application Cases
5. 结语
Concluding Remarks

TPRI

1.国内SCR技术的应用现状
Current Application Situation in China(1) 国内燃煤锅炉SCR应用情况
Current Application Situation on Utility Boilers in China●已投运、在建和拟建的SCR项目超过100个
The number of SCR projects, either commissioned, or in
erection, or planned has exceeded 100●脱硝效率要求一般在50∼80%
Required DeNOx efficiency normally 50∼80%(2) 国内SCR工程公司技术情况SCR Technical Situation in China●以国外技术为依托，采取项目合作、技术引进、组建合资公司等方式参与SCR工程建设
Supported by foreign companies in ways of project
cooperation, technology import, forming joint venturecompany etc.
●技术来源包括日本、欧洲及美国各流派的SCR技术The SCR technologies originate in Japan, Europe and USA.

TPRI

2.煤质和锅炉特点对SCR催化剂的影响Influences of Coal Property and Boiler Type on SCR Catalyst(1) 煤质的影响
Influences of Coal Property●As2O3的影响
Influences of As2O3●可溶性碱金属氧化物 (Na2O与 K2O )Influences of Na2O and K2O●碱土金属氧化物（CaO与MgO）
Influences of CaO and MgO●烟气温度的影响
Influences of flue gas temperature●烟气中飞灰的影响
Influences of fly ash in flue gas

TPRI 2.煤质和锅炉特点对SCR催化剂的影响

2.煤质和锅炉特点对SCR催化剂的影响Influences of Coal Property and Boiler Type on SCR Catalyst(2) 炉型的影响 Influences of Boiler Type项目 Item

SCR入口烟尘
Dust at Inlet of
SCR

炉内初始As2O3
As2O3 in
Furnace

SCR入口As2O3
As2O3 at Inlet of
SCR单位 Unit

g/m3

µg/m3

µg/m3

固态排渣 Dry Bottom

15

750

<5

液态排渣，无飞灰复燃
Slag Tap Boiler Without
Fly Ash Recycle

14

750

<20

25

10000

1000

液态排渣炉，100%飞
灰复燃
Slag Tap Boiler With
100% Fly Ash Recycle

TPRI

3.中国动力用煤与炉型特点
Properties of Chinese Steam Coals(1) 煤质特点 Properties of Coals●煤覆盖范围广，包括褐煤、高挥发分烟煤、贫瘦烟煤及无烟
煤等
The coals fired in Chinese utility boilers show very wide
spectrum, covering lignite, high volatile bituminous coals,
lean coals and anthracite coals.
●低位发热量集中在19∼26MJ/kg，部分煤种发热量低于
18MJ/kg
The low heating values of the coals are mainly in the rangeof 19-26MJ/kg, several coals have heating values below 18
MJ/kg.

TPRI

3.中国动力用煤与炉型特点
Properties of Chinese Steam Coals(1) 煤质特点－灰含量 Properties of Coals - Ash Content

7060
收到基灰 %

收到基灰集中在10∼30%，少量优质烟煤低于10%，相当数
量灰含量超过30%，甚至高达
45%左右。
The majority of coals haveash content in medium tohigh range with 10-30%,
few quality bituminous coals
have ash content below
10%, while a considerable
number of coals have ash
content above 30%, evenas high as 45%.

50
40
30
20
10
0
0

100

200

300
煤种

400

500

600

TPRI

3.中国动力用煤与炉型特点
Properties of Chinese Steam Coals(1) 煤质特点-硫含量 Properties of Coals - Sulfur Content

The majority of coals
have sulfur content
below 2%, few haveover 3%, even 5%
sulfur.

65
收到基硫 %

多数低于2.0%
少量超过3.0%，甚至达
到5.0%.

4
3
2
1
0
0

200

400
煤种

600

TPRI

3.中国动力用煤与炉型特点
Properties of Chinese Steam Coals(1) 煤质特点-矿物组成 Ash Constituents●SiO2与Al2O3之和，多数集中在60∼80%，少数低于60%，部分达到80∼90%The sum of SiO2 and Al2O3 mainly falls in the range 60-80%,
with few exceptions of below 60% or over 80%.
●Na2O与K2O含量较低，只有1∼3%
The alkali metal oxides Na2O and K2O are low with 1-3%.
●CaO与MgO含量之和多数低于12%，少数接近25%
The CaO and MgO add up mainly below 12%, with a few closeto 25%.

TPRI

3.中国动力用煤与炉型特点
Properties of Chinese Steam Coals(1) 煤质特点-飞灰粒径分布 Fly ash particles size distribution

Cumulative percentage, %小于累积体积 / %

100
80
60

常规
煤种B
煤种C

40
20
0
0.01

0.1

1
10
飞灰粒径 /μm

100

Fly ash particle size, microns

1000

TPRI

3.中国动力用煤与炉型特点
Properties of Chinese Steam Coals(2) 炉型特点

Types of Boiler●切园燃烧

Tangential firing●墙式燃烧Wall firing●“W”火焰炉 Down shot flame●液态排渣炉 Slag tap furnace
日常燃煤品质很不稳定The quality of coals as fired in Chinese utility boilers is usuallysubject to big fluctuations due to improper blending oralternate supply of different coal types to the boilers.

TPRI

4.工程实例介绍Industrial Application Cases(1) 液态排渣炉改造实例
SCR Retrofit Case on Slag Tap Boiler●燃用灰含量很少且熔点较低的烟煤
Low ash content and low ash fusion temperature bituminous coal●约有一半的灰被熔成炉渣
About half of the ash in coal exits the furnace as granulated slag●烟气中的飞灰浓度约2.7∼9.8g/Nm3
Fly ash concentration in flue gas is 2.7∼9.8g/Nm3●灰中SiO2、Al2O3含量较低，Fe2O3、CaO、MgO含量较高，飞灰
具有中等级别的粘污特性
Low SiO2 and Al2O3 , high Fe2O3, CaO and MgO in fly ash, withmedium adhesive property.

TPRI

4.工程实例介绍Industrial Application Cases(1) 液态排渣炉改造实例
SCR Retrofit Case on Slag Tap Boiler●除尘器第一电场飞灰粒度小于1μm的颗粒超过20%，小于
10μm的颗粒约占65%，飞灰粒径细小，具有较强的粘附特性
The ash sample from the first field hopper is over 20% finer
than 1 micron, about 65% finer than 10 microns. The ash
samples from the other three fields are 89-90% finer than 5
microns. The fly ash is as a whole very fine and adhesion
prone.

TPRI

4.工程实例介绍Industrial Application Cases(1) 液态排渣炉改造实例
SCR Retrofit Case on Slag Tap Boiler

炉内受热管之间的飞灰搭桥空预器高温段受热面飞灰堵塞
Ash bridge between tubes in boiler
Ash plugging in AH hightemperature heating surface

TPRI

4.工程实例介绍Industrial Application Cases(1)液态排渣炉改造实例-针对性措施
SCR Retrofit Case on Slag Tap Boiler-Pertinent measures●通过CFD数值模拟与物理模型试验优化烟气流场，减少飞灰在导流与整流板上的堆积。
Optimize the flow pattern through CFD simulation andphysical model test, minimizing the deposition of fly ash on
the guiding vanes and flow rectifiers●采用耙式蒸汽吹灰器与声波吹灰器相结合的吹灰策略 。
Apply rake type steam soot blowers together the sonic horns

TPRI

4.工程实例介绍Industrial Application Cases(1) 液态排渣炉改造实例-针对性措施
SCR Retrofit Case on Slag Tap Boiler -Pertinent measures●选用节距相对较大的催化剂，提高催化剂的通流面积，减少催化剂易积灰的角部数量。
Apply catalysts with large pitch size to increase flow areaof the catalysts and reduce the number of corners which
are prone to ash deposition●采用“3＋1”催化剂布置模式，缩短单层催化剂高度，增强吹灰效果 。
Arrange the catalyst layers in “3＋1” mode to reduce theheight of single catalyst layers and enhance theeffectiveness of soot blowing●相应提高催化剂内的烟气流速，增加烟气对催化剂表面积垢的剪切冲击力 。
Increase the flow velocity with the catalysts to better wash
out the ash deposition on the catalyst surfaces

TPRI

4.工程实例介绍Industrial Application Cases(2) 固态排渣炉SCR改造实例
SCR Retrofit Case on Dry Bottom Boiler●实际燃煤来源和品质较杂，入炉煤的品质波动较大，灰含量
约为25∼40%，硫含量约为0.3∼1.4%，低位发热量约为
17∼25MJ/kg。
The instable supply of coals leads to great fluctuation of the coalproperty in terms of ash content ranging from 25 to 40%, sulfur
content ranging from 0.3 to 1.4% and the low calorific value
ranging from 17 to 25 MJ/kg.

●CaO与MgO含量较低；Na2O与K2O含量之和小于1.5%；
SiO2与Al2O3含量之和达到84.9%。飞灰的粘性较低，硬度较
高。
The ash has low CaO and MgO content, and Na2O and K2O add
up below 1.5%, while SiO2 and Al2O3 add up to 84.9%. The fly ash
has low adhesiveness but great hardness.

TPRI

4.工程实例介绍Industrial Application Cases(2) 固态排渣炉SCR改造实例
SCR Retrofit Case on Dry Bottom Boiler●飞灰粒径超过100μm的颗粒所占体积比例接近80%，其中
含量最高的是粒度约为200μm颗粒。
The fly ash particles greater than 100 microns account fornearly 80%, and particles around 200 microns are mostavailable.
●锅炉燃煤品质多变，飞灰含量高、粒度大、硬度高，具有较强的冲蚀磨损特性
The great fluctuation of coal quality, very high fly ashloading, coarse and hard fly ash particles lead to severe
erosionTPRI

4.工程实例介绍Industrial Application Cases(2) 高灰固态排渣炉SCR改造实例-针对性措施
SCR Retrofit Case on Dry Bottom Boiler-Pertinent measures●脱硝反应器布置在省煤器与空预器之间每台炉布置两个反应器
Arrange in parallel two SCR reactors between theeconomizer and the air heater●催化剂采用抗堵塞与冲蚀磨损性强的板式，按“2＋1”模式安装，节距为7mm
Apply plate type catalysts, in 7mm pitch size and "2＋1"
arrangement, to minimize erosion and plugging problems

TPRI

4.工程实例介绍Industrial Application Cases(2) 高灰固态排渣炉SCR改造实例-针对性措施
SCR Retrofit Case on Dry Bottom Boiler -Pertinent measures●采用CFD模拟与物理模型试验优化SCR入口上游烟道结构、灰斗、喷氨格栅、导流与整流装置，在除灰与防止飞灰堆积的同时，强化顶层催化剂入口的烟气速度、角度、温度及NH3/NO
摩尔比的均匀性
Optimize the duct construction upstream of the reactors, ashhoppers, AIG, guiding vanes and flow rectifiers through CFD
simulation and physical model test, to remove part of the fly
ash beforehand and prevent deposition of fly ash, andequalize as far as possible the velocity profile, flow direction,
temperature profile and NH3/NO molar ratio at inlet of thefirst catalyst layer

TPRI

4.工程实例介绍Industrial Application Cases(2) 高灰固态排渣炉SCR改造实例-针对性措施
SCR Retrofit Case on Dry Bottom Boiler- Pertinent measures●吹灰器采用声波与耙式蒸汽吹灰相结合的吹灰策略，先期安装声波吹灰器，并预留耙式蒸汽吹灰器。
Apply both sonic horns and rake type soot blowers. In thefirst place install the sonic horns, while the rake type sootblowers are designed as reserve●空预器受热面由三段改为两段，冷段能涵盖NH4HSO4的液态
温度范围，并在受热面上镀搪瓷 。
Arrange the heating surfaces of the air heater in two stages
instead of three, enamelize the heating surfaces of the cold
stage, which operates in temperature range the ammonium
bisulfate forms

TPRI

4.工程实例介绍Industrial Application Cases(3)高钙烟煤新建SCR项目New SCR project with high Calcium bituminous coal
● 国内部分新建600MW级机组燃用高钙神华烟煤，飞灰粒度相对较
细，具有一定的粘结性。某工程的空预器采取不拉出布置方式，
SCR反应器布置在省煤器与空预器之间。受空间尺寸的限制，SCR
反应器入口烟道较短，流场分布相对不均匀。催化剂采用小节距的蜂窝式，按“2＋1”模式布置，采用声波吹灰器吹灰。
Many newly built 600MW generating units are designed to burnhigh Calcium Shenhua bituminous coal, the fly ash is usually fineand adhesive. The boiler has a built in air heater. The SCR
reactor is arranged between the economizer and air heater in very
constrained space, so that the inlet flue duct to the SCR reactor isvery short, resulting in uneven velocity distribution of the flue gas.
The catalysts are of small pitched honeycomb type in “2＋1”arrangement, sonic horns are used to clean the catalysts.

TPRI

4.工程实例介绍Industrial Application Cases(3)高钙烟煤新建SCR项目New SCR project with high Calcium bituminous coal●通烟气仅1个月后，催化剂孔道虽然没有堵塞，但孔道内表面粘附了一层飞灰，这可能会影响烟气中的NH3与NO向催化剂表面扩散，进而影响脱硝性能。
After only one month of operation, the catalyst surfaces
are fouled with fly ash, although the flow paths are notplugged. This fouling will retard the diffusion of NH3 and NO
to the catalyst surfaces and further the deNOx performanceof the SCR.

TPRI

5.结 语
Concluding Remarks(1) 国内部分动力用煤具有高灰、高钙、高硫、高粘性、灰冲刷磨损性强及同一机组煤质不稳定波动范围大以及机组普遍参与调
峰运行等鲜明特点，应在我国电站锅炉应用SCR技术时综合考虑，有针对性地选择各主要参数，而不能完全照搬国外的经验。
A considerable number of Chinese steam coals arecharacterized by high ash, high Calcium, high sulfur, adhesiveand erosive fly ash, and furthermore qualitatively very different
coals are often burned in the same boiler, and most of thegenerating units operate in peak load mode. These special
conditions must be jointly taken into account when applying of
the SCR technology on Chinese utility boilers; the criticalparameters must be selected in pertinence to every specificcondition. Existing experiences could not be simply copied.

TPRI

5.结 语
Concluding Remarks(2) SCR技术在中国尚处于消化、吸收阶段，在借鉴国外SCR技术应用经验的基础上，通过国内SCR工程实践不断积累经验，掌握适合中国特点的SCR技术。
China is in the stage of digestion and absorption of import SCR
technology. On the basis of existing foreign experiences, own
practical experiences should be in the course of industrial
applications amassed, to have good command of the SCR
technology in pertinence to China specific conditions.

TPRI

谢谢!
Thank you for your attention！

Day 3 Wednesday 17 October 2007
Session 9: Flue Gas Cleaning Technology

Speech 2 US
New Technologies for Emissions Reduction and Steam Plant
Efficiency Improvements

Mr. Tom Dendy
Director
Global Market & Application Development
SPX Thermal Equipment & Services
USNew Technologies for Emissions
Reduction and Power Plant
Efficiency Improvements减少废气排放和改善电厂效率的新技术
October 15, 20072007年10月15日

New Technology Impact 新技术的影响
Cooling System Upgrades
1% to 2.5% reduction in fuel consumption
Corresponding 1 to 2.5% emissions reduction
Electrostatic Precipitator Upgrade
40% Reduction in particulate emission

冷却系统升级
燃料消耗量减少1% - 2.5%
废气排放量相应减少1% - 2.5%
静电除尘器升级
微粒排放量减少40%

2007/10/23

2

Steam Plant Efficiency 电厂效率
Waste Heat (combustion)

od
r
P
W
力
M
电
的

废热（燃烧）

u

生
产
d
ce

Thot
Waste Heat 废热

Tcold

Fuel Consumed 消耗的燃料
2007/10/23

3

Steam Plant Efficiency 电厂效率

Maximum Efficiency =极大效率Thot – Tcold
Tcold

Maximum THEORETICAL Efficiency is a function of:Heat Source Temperature (Steam Temp)
Heat Sink Temperature (Cooling System Temp)
极大理论效率是：热源温度（蒸汽温度）
冷源温度（冷却系统温度）的函数
2007/10/23

4

PowerPlant Efficiency 电厂效率
Waste Heat (combustion)废热（燃烧）
od
r
P
W
力
M
电
的

Thot

u

产
生
d
ce

Waste Heat 废热

Tcold

Fuel Consumed

Efficiency =消耗的燃料
2007/10/23

效率

MW Produced

生产的电力Fuel Consumed

消耗的燃料
5

设
计
热
耗
率
%

% of Design Heat Rate

Heat Rate vs Cold Water Temperature热耗率与冷水温度关系
104.5%
104.0%
103.5%
103.0%
102.5%
102.0%
101.5%
101.0%
100.5%
100.0%
99.5%
99.0%
25

27

29

31

33

35

CWIT, C 冷水温度 oC

Typical Power Plant Heat Rate Curve
10°C Temperature rise Æ 4% rise in fuel consumption
典型电厂热耗率曲线
10°C温升Æ 增加4% 燃料消耗

2007/10/23

6What Raises Cold Water Temperature?
什么因素使冷水温度上升？
For a given design, Cold Water temp rises with:
1. reduction of cooling tower air flow
2. reduction of cooling water flow
3. increase of ambient wet bulb temperature
在特定设计下，冷水温度升高与下列因素有关：
1. 冷却风量减少2. 循环水量减少
3. 环境湿球温度升高典型冷却塔性能曲线

Typical Cooling Tower Performance Curve

出
水
温
度

Tower Outlet, (C)

40
35
30
25
20
15
-7
2007/10/23

-1

4

10

16

Wet Bulb, (C)

湿球温度

21
7

How do we REDUCE Temperature?
如何降低温度？

出水温度

Tower Outlet, (C)

40
35
30
25
20
15
-7

-1

4

10

16

Wet Bulb, (C)

湿球温度

21

Upgrades to heat transfer media can shift curve

使热传媒介升级可使曲线下移
2007/10/23

8

DF 254 High Performance Fill
DF 254高效填料
Introduced in 2005
Low Clog Fill – dirty water
application
25.4 mm sheet spacing
Colder water vs. existing fills
2005年问世
低度堵塞填料 - 浊水应用
片距25.4毫米
与现有填料相比可使水温更冷

2007/10/23

9Fuel Savings case study
燃料节省个案研究
Monthly Fuel Savings 每月燃料节省率

燃
料
节
省
百
分
比

Percent Fuel Savings

3.0%
2.5%
2.0%
1.5%
1.0%
0.5%
0.0%
Jan

Feb

Mar

Apr

May

Jun

Jul

Aug

Sep

Oct

Nov

Dec

Less Fuel = Less Pollution
少燃料 = 少污染2007/10/23

10Other Upgrade Project Case Studies
其他升级项目个案研究
Mechanical Draft Cooling Towers- Conversion from cross-flow to counter-flow- Media upgrade- Tower re-design and optimization
Natural Draft Cooling Towers- Conversion from cross-flow to counterflow- Media upgrade- Balancing air distribution- “Helper Tower” installation
机械通风冷却塔- 横流塔改为逆流塔- 填料升级
- 冷却塔重新设计并优化
自然通风冷却塔- 横流塔改为逆流塔- 填料升级
- 平衡空气分布
- 安装“辅助冷却塔”
2007/10/23

11

Flue Gas De-dusting Innovations烟气除尘创新技术
Technology to Increase the Removal of Fine Particles

Flow Optimisation and Particle Distribution Homogenization

Efficiency Improvements with High Frequency Switch Mode
Power Supplies

新技术增加除尘能力流场优化和微粒分布均匀化高频电门模式供电改善效率
2007/10/23

12

The ESP Conflict
静电除尘的矛盾Electrostatic Precipitators (ESP)
1. “Charge” entrained particles Æ high electrical current
2. “Collect” charged particles Æ high voltage (low current)High current inhibits collection静电除尘
1. 使颗粒“负荷” Æ 需要高安电流
2. “收集” 负荷颗粒 Æ 需要高伏（低安电流）高安电流抑制收集

2007/10/23

13

Prior Technical Solutions
新技术解决方案之前
Principle of a conventional Electrostatic Precipitator
常规静电除尘原理

Particle charging and collection in thesame area of the electrical field颗粒负荷和收集在同一个电场区域

2007/10/23

电流

14

New Technology: Bi-Corona®
新技术： Bi-Corona

Double Lane Bi-Corona®-Technology
双巷Bi-Corona® - 技术

2007/10/23

Collecting area

Discharge area

收集区

放电区

Single Lane Bi-Corona®-Technology
单巷Bi-Corona® - 技术Collecting area

Discharge area

收集区

放电区

15

Pilot ESP manufacturing实验除尘器制造2007/10/23

Pilot ESP in Neurath PS
Neurath电厂实验除尘器

16

0.31
0.33
0.35
0.38
0.41
0.44
0.47
0.51
0.54
0.58
0.63
0.67
0.72
0.78
0.84
0.9
0.97
1.04
1.12
1.2
1.29
1.38
1.49
1.6
1.72
1.85
1.98
2.13
2.29
2.46
2.64
2.84
3.05
3.28
3.53
3.79
4.07
4.37
4.7
5.05
5.43
5.83
6.27
6.74
7.24
7.78
8.36
8.98
9.65
10.4
11.1
12
12.9
13.8
14.9
16
17.2

Particulate Emissions
微粒排放物

Raw Gas 原料气体Conventional ESP 常规除尘
BiCorona 新技术

75% Emissions Reduction
降低75% 的排放物

2007/10/23
17

ESP Performance Issues
静电除尘的问题
 Flow imbalance – up to 30% performance reduction
 流体不平衡– 性能可降低至30%

Gas distribution walls烟气分配壁2007/10/23

18

Flow Optimization & Modeling
流体的优化和模拟
DELTA WING® - Function ESP
三角翼 – 功能性静电除尘

DELTA WING® - Optimization ESP
三角翼- 优化性静电除尘

Fluid homogenisation anddestruction of streaks bymeans of vortex generation
产生涡流使流体均匀化和破坏不均匀流体
2007/10/23

19

Optimized Flow
优化的流场Flue gas optimisation – CFD-Method烟气优化 – CFD (计算流体动力学法)
After conversion of gas
distribution walls转换烟气分配壁后

Before optimisation 优化前

Gas distribution walls烟气分配壁2007/10/23

20

Spannung [kV]Spannung [kV]

New Generation ESP Power Supply
新生代静电除尘供电

US
US

UD

UD

UM

UM

Zeit

Zeit

Voltage Characteristic ofConv. T/R-Set

Voltage Charact. of HighFrequency T/R-Set

常规电压特征曲线

高频电门供电
电压特征曲线

 High Frequency Switch mode power Supply
 ~20% reduction in energy consumption
 高频电门模式供电 可减少~20% 的能耗
2007/10/23

21

Emission Reduction Strategy
减少排放物的策略
 Use less fuel• Increase steam cycle efficiency• Reduce energy consumption on ESP

 Upgrade ESP Systems• Less particulate discharge• Less energy consumption 减少燃料用量••

增加蒸汽循环效率
减少静电除尘能耗

 静电除尘系统升级
••
2007/10/23

微粒放电较少能耗较少

22Day 3 Wednesday 17 October 2007
Session 9: Flue Gas Cleaning Technology

Speech 3 Indonesia
High-Efficiency SO2 Removal Using Activated Carbon Fibers

Dr. Miftahul Huda
Senior Researcher
Coal & Mineral Technology R&D Centre
Agency of R&D for Energy and Mineral Resources
Ministry of Energy and Mineral Resources (MEMR)
Indonesia

High-Efficiency SO2 Removal
Using Activated Carbon Fiber

By: Miftahul Huda

Mineral & Coal Technology R&D Center
Agency of R & D For Energy and Mineral Resources
Ministry of Energy and Mineral Resources

Xi’an, PRC October 15– 17, 2007

1

Conventional Flue Gas Desulphurization
Process (wet process using Ca(OH)2):•High Investment Cost
•Consume much of water•Low value of by product (CaSO4)•Unable to remove SO2 Completely(>30 ppm leaked)

Zero SO2 Emission

Activated Carbon
Fiber (ACF)2

Desulphurization Mechanism by ACF
SO2

H2O

H2O

SO3 (ad.)ACF surface
ACF surface

H2SO4 (ad.)

O2

SO2 (ad.)aq. H2SO4

Factors Influence The Desulphurization Performance
1. Surface Area and Microporosity
2. Surface Chemistry(active sites and acidity)
3. Hydrophobicity

Activation method,
Precursor, etc

Oxidation, impregnation
with metal, Heat Treatment

Heat treatment
3Active Site Formed by Heat Treatment
HT

+

CO
CO2

1100oC
ACF
S

S

S

S
S

+ H2O
S S

S S

S

= active site; S = SO3+ H2SO4

Objective of this work:
Reducing the cost of ACF by increasing its Activity for SO2
RemovalApproach: Modification of Surface Chemistry
Method :Oxidation of ACF
With LOG (Low Oxygen
Gas or O2 <5%, N2 Base)

Active Site

Other methods
1. Introduction of nitrogen
2. Oxidation with aqueous
oxidant (HNO3)
3. Oxidation with gaseous
oxidant (Air)

Ammonia expensive
Surface area decreased andacidity increased
Cheap but difficult to becontrolled
5CHARACTERISTICS OFPITCH DERIVED ACF(OG15A)ACF

Granular Activated Carbon

Surface
Area

Contents (wt. %)ACF (OG15A)

H

C

N

O

Ash

(m2/g)

0.67

90.68

0.35

8.30

1

1450

Flow Sheet for the experimental work
ACF

ACF or Fe/ACF(Fe impregnated
ACF)

Oxidation
Treatments

Heat Treatments
1100oC under Ar

Desulphurization
Experiment7

thermocouple
Gas inlet
Gas outlet

OXIDATION
APPARATUS AND
CONDITIONS

Oxidation Conditions:

ACF
Gasdistributor

Gas flow rate = 1L/min
Gas compositions= O2:2,
6, 21% and N2 Base
ACF weight = 1gram
Oxidation time = 1 hr
T-ox= 350-550oC
8

100

Result of ACF
Oxidation Treatment

90

Yield (%, wt.)

80
70
60

Note:

ACF-ox21%T42
ACF-ox6%T40
ACF-ox6%T50
ACF-ox2%T55
0.5%Fe/ACF-ox2%T35
0.5%Fe/ACF-ox2%T40
0.5%Fe/ACF-ox2%T45

50
40
30
20
10

ACF-ox2%T55t3 = ACF
oxidized with 2% oxygen at
550oCfor 3 hrs

0
0

1

2

3

4

0.5%Fe/ACF = 0.5%Fe
impregnated in ACF

Time (hrs)ACF

ACF-ox2%T55t1

ACF-ox2%T55t3

9

De-Sox Apparatus Configuration andExperimental Conditions
ExhaustH2O
FlamePhotometric
Detector

Flow
Controller
N2

SO2 Air

Temperature
Controller

Reactoraq.H2SO4

ACF
Gas compositions= SO2:1000ppm, O2=5 Vol.%,
H2O=10 Vol.%, N2=balance, Raction temperature =50oC Gas flow rate = 100mL/min

H2SO4
10

100

H2O=10% Vol.

SO2 outlet/inlet (%)

90
80
70
60

ACF
ACF-ox2%T55t0.5
ACF-ox2%T55t1
ACF-ox2%T55t2
ACF-ox2%T55t3

50
40
30
20

inlet gas = 1000ppm
acf=0.1gram

10

Influences of
ACFs oxidation
to theirdesulphurization
activity

0
0

1

2

3

4

5

6

7

8

9 10 11 12 13 14 15Time (hrs)
Note : All the ACFs were heat treated under argon gas at heating rate
10K/min to 1100oC before SO2 removal experiments
11

Influences of Fe/ACFs oxidation totheir desulphurization activity
100

inlet gas = 1000ppm; acf=0.1gramSO2 outlet/inlet (%)

90
80
70
60
50
40
30
20
10

H2O=10%ACF
0.5%Fe/ACF-ox2%T35t1
0.5%Fe/ACF-ox2%T40t1
0.5%Fe/ACF-ox2%T45t1

0
0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15Time (hrs)12Correlation between weight loss
during heat treatment (HT) andamount of SO2 removal
Converted SO 2 (ml)

600
500
400
300
200

ACF-ox100

Fe/ACF-ox

0
0

5

10

15

20

weight loss during HT at
1100 o C

25

13

Influences of SO2 concentrations on thedesulphurization activity of oxidized ACF

SO2 outlet/inlet (%)

100
90
80
70
60
50
40

ACF-ox55t2-1000ppm
ACF-ox55t2-700ppm
ACF-ox55t2-500ppm
ACF-ox55t2-300ppm
H2O=15% Vol.
ACF=0.1gram

0.03 ml/min/gr
0.0385 ml/min/gr
H2SO4 Elution Rate
0.04ml/min/gr

30
20
10
0
0 5 10 15 20 25 30 35 40 45 50 55 60 65 70

Time (hrs)14Influences the amountdesulphurization activityofoxidized

ACF

on

the

SO2 outlet/inlet (%)

100
90
ACF-ox2%T55t2-0.1gr
80
ACF-ox2%T55t2-0.2gr
70
ACF-ox2%T55t2-0.3gr
60
H2O=15% Vol. and Inlet gas
50=1000ppm
40
Figure 30
5.11 Influences of water concentration on the desulphurization activity of ACF and oxidized ACF
20
10
0
0

10

20

30

40

50

60

70

80

90 100 110 120 130 140 150 160 170

Time (hrs)Breakthrough timefor SO2 removal

0.1 gr oxidized ACF= 2 hrs
0.2 gr oxidized ACF= 30 hrs
0.3 gr oxidized ACF=110 hrs

15

Proposed Desulphurization Mechanism by ACF

SO2

O2

SO2 (ad.)SO2 charging
rate

H2O

H2O

SO3 (ad.)ACF surface
ACF surface

H2SO4 (ad.)

Should be Smaller thanaq. H2SO4
H2SO4
discharging
Rate

CONCLUSIONS
1. The Desulphurization Activity of ACF canbe enhanced by Oxidation Treatment
2. The Oxidation increased Surface Area andActive Site of The ACF
3. Longer breakthrough time of SO2 removal
was achieved when SO2 charging rate issmaller than H2SO4 discharging rate

17

Thank You

18

Vol. adsorb (cm3/g)

700

Nitrogen Isothermof ACFs and theirpore volume

600
500
400
300

ACF

200

0.5%Fe/ACF-ox2%T45t1

100

ACF-ox2%T55t2

0
0.0

0.2

0.4

0.6

0.8

1.0

P/Po
micropore total pore BET SA
cm3/g
m2/g
cm3/g
ACF
0.55
0.57
1523
0.5%Fe/ACF-ox2%T45t1
0.62
0.88
1671
ACF-ox2%T55t2
0.65
0.86
1751

19

0.5

acf
0.5% Fe/ACF-ox2%T35t1
0.5%Fe/ACF-ox2%T45t1
ACF-ox2%T55t2
ACF-ox2%T55t3

ml/min/gr

0.4
0.3
0.2

CO2

0.1
0

ml/min/g .

CO and CO2
desorption profiles of
ACFs

100

6

200

300

400

500

600

700

Temperature (oC)

800

acf
0.5%Fe/ACF-ox2%T35t1
0.5%Fe/ACF-ox2%T45t1
ACF-ox2%T55t2
ACF-ox2%T55t3

5
4
3
2

900 1000

CO

1
0
100

200

300

400

500

600

700

o

Temperature ( C)

800

900 100020

Influences of SO2 concentrations on
the desulphurization activity of ACF
100
90
80
70
60
50
40
30
20
10
0

SO2 outlet/inlet (%)

H2O=15%
ACF=0.1gram

ACF-1000pm
ACF-700ppm
ACF-500ppm
ACF-300ppm

0.022 ml/min/gr
0.028 ml/min/gr
H2SO4 Elution Rate
0.0335ml/min/gr

0

5 10 15 20 25 30 35 40 45 50 55

Time (hrs)21

Influences the amount of ACF on thedesulphurization activity of ACF
100

SO2 outlet/inlet (%)

90

ACF-0.1gr

ACF-0.2gr

ACF-0.3gr

ACF-0.4gr

80
70

Breakthrough timefor SO2 removal

60
50
40

H2O=15% Vol.
Inlet gas =1000ppm

30
20
10

0.1 gr ACF= 1 hr
0.2 gr ACF= 5 hrs
0.3 gr ACF=10 hrs

00

5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85

Time (hrs)
22

0.08
0.07
0.06
0.05
0.04
0.03
0.02
0.01
0.00
-0.01

OG15A
ACF
RAW
(cm3/gr)/A(cm3/gr)/A

PORE SIZE DISTRIBUTION OF ACF

1

10
Radius (A)100

RAW ACF (OG15A)

Fe2O3

ACF-0.5Fe30ox20h

110Radius (A)100

Oxidized ACF(0.5Fe30ox15h)

Catalyst/(Fe(NO3)3
Adsorption

ACF
Fe(NO3)3

0.08
0.07
0.06
0.05
0.04
0.03
0.02
0.01
0.00
-0.01

Oxidation

Day 3 Wednesday 17 October 2007
Session 9: Flue Gas Cleaning Technology

Speech 4 PR China
SCR Key Technical Choice for Coal-fired Power Plants Removal
Nitrogen Oxides

Dr. Zhang Qiang
Head
SCR Group
Thermal Power Research Institute (TPRI)PR China

TPRI张强
工学博士，研究员；主要从事洁净煤技术的科学研究与技术开发工作。
其中，在燃煤电站SCR脱硝方面的主要成就有：作为课题负责人先后完成了“选择性催化还原（SCR）催化剂的研究与开发”、“选择性催化还原（SCR）工艺的研究与开发”及“大型火电机组SCR脱硝催化剂的工程应用开发”、“燃煤电站烟气脱硝新技术研
究”等相关课题研究。
作为发明人授予了“一种用于电站烟气SCR脱硝中的催化剂及其制做方法（专利号为：200410026287.1）”国家发明专利。
开发的“燃煤电站烟气脱氮SCR工艺TPRI-I型催化剂”产品获得了国家科技部、国家
商务部、国家质量监督检验检疫总局及国家环保总局联合颁发的2005年国家重点新产品证书（证书编号：2005ED850018）。
作为第一作者在国内外公开出版的刊物上发表论文50余篇。
出版了一本《燃煤电站SCR烟气脱硝技术与工程应用》专著（2007年8月）。
获得陕西省科技进步二等奖一项、三等奖一项，中国电力科学科技进步二等奖一项
。
作为电力行业脱硝领域专家，先后多次参加国内脱硝项目的可行性研究、标书审查、工程评标或设计审查等工作。

TPRI

SCR Key Technic Choice for Coal-fired
Power Plants Removal Nitrogen Oxides

Zhang Qiang[PhD]

Xi’an Thermal Power Research Institute Co., Ltd.
October. 16, 2007

TPRI

Table of Contents

1. State environment policy and SCR technology
2. SCR reducant
3. SCR catalyst
4. SCR reactor and bypass
5. Ammonia injection and mix
6. Clear ash method
7. Summary

TPRI

1.State environment policy and SCR technology

1 State environment policy¾ GB13223-2003;NOX;450mg/m3;¾ China will actualize nitrogen oxides gross control assoon as possible;¾ New NOX rule of low will be printsman after 2009;¾ NOX allowable let concentration is different from region;¾ So we suggest the power plants located in importantarea, economy upgrowth area and landscape area build
in SCR equipment first.
2 SCR technology

TPRI
1.State environment policy and SCR technology

Urea + NOx---> N2 + CO2 + H2O
NH3 + NOx + O2 ---> N2 + H2O

TPRI

1.State environment policy and SCR technology

TPRI

1.State environment policy and SCR technology¾ deNOX technology: Low NOX burners、SCR、SNCR;¾ For new build power plants, NOX concentration isrequired below 400mg/Nm3（bituminous）.If want to
reduce further, need to equip SCR system.

¾ For reform program, if want to control NOX concentration,

first measure actual NOX concentration, then carrythrough burner becoming low NOX burner, NOX
concentration is reduce, last consider other flue gas
deNOX.

TPRI

2. SCR reducant¾ In SCR system, reducing agent is divided into threeclass, one is anhydrous ammonia, ammonia waterliquid and urea.
¾ Three reducant compare as follow.

TPRI

2. SCR reducant

title

anhydrous
ammoniaammonia waterliquidurea

Buy costs

middling costly

cheap

costlyTransport
costs

cheap

costlycheap

safethvenonousness

nocuousness

innocuity

deposited
conditionhigh presure

general presure

general presure，dry

depositedmannerliquid stateliquid stateparticulate

early invest
costs

cheap

costlycostlyrun costs

cheap

costlycostlyequipment
safetyrequestlaw regulate

need

No needTPRI

3.SCR catalyst¾ SCR catalyst

High temperature catalyst: > 400℃
middling temperature catalyst: 300-400℃
low temperature catalyst: <300℃¾ At present, V2O5-WO3(MoO3)/TiO2

TPRI

3.SCR catalyst¾ Honeycomb, plate state, corrugation state.

TPRI

3.SCR catalyst¾ Selective catalyst must meet

performance parameter, at least include
in:deNOX efficiency meet request
NH3 escape concentration: ≤3ppm;
SO2 to SO3 transform efficiency: ≤1%

TPRI

3.SCR catalyst¾ Catalyst chemistry life: 16000h, 20000h, 24000h¾ High ash, high calcium and other gravenessinfluencing catalyst chemistry life coal: 16000h¾ Better coal, a little influencing catalyst chemistry life

coal: 24000h¾ Between above two: 20000h¾ Catalyst machine life: ≥10 years

TPRI

3.SCR catalyst¾ Continuum run: 300-400℃¾ More 5 hours extremity run: 420℃
¾ Catalyst pitch: catalyst manufacturer determine, ashhigh pitch big.

TPRI

4. SCR reactor and bypass¾ SCR reactor located: high ash location, low ash

location and tail location, determination by power
plants actual condition.
¾ We suggest SCR reactor high ash location for newbuilding power plants.
1temperature;2space;¾ For old power plants reconstruct, first suggest

high ash location. When SCR reactor is limited by
space or others, consider others locations.
1:question for ESP running high temperature;2:question of flue gas reheat.

TPRI

4. SCR reactor and bypass¾ Byposs

Economizer byposs: adjust reactor temperature;
SCR reactor byposs: when reactor examine andreplace catalyst, SCR system work in gear.
Disadvantage: increase byposs flue, support steel
structure, coat increase.
Suggestion: If only condition permission, byposs
doesn’t need to design.

TPRI

5.Ammonia injection and mix¾ Optimisation design for mixing of ammonia

and NOX.
¾ Mixing system is composed of sprayequipment and leading flow equipment.
¾ Conventional AIG. show as follow

TPRI

Conventional AIG

TPRI

5.Ammonia injection and mix¾ Improved product:

Technic advantage: (1)flux adjust on feed tube;(2) static state mixing vanes install on every nozzle below.

TPRI

5.Ammonia injection and mix

FBE(FISIA BABCOCK ENVIRONMENT GmbH) Vortex mixer

Technic advantage: (1)reduce inject hole; (2)reduce jam probability;(3)control simplement; (4)pressure drop low

TPRI

5.Ammonia injection and mix¾ BALCKE DURR(巴克-杜尔)DELTA WING mixer.

Technic advantage: (1)mix distance short;(2)pressure drop low;(3)structure simplenessTPRI

5.Ammonia injection and mix¾ Considered factor for choice ammonia injection

and mixing system:(1)Length and location of SCR reactor forepart flue;(2)Pressure drop;(3)Mixing distance;(4)Investion cost and running cost(5)Installation agility

TPRI

6.Clear ash method¾ Steam blower, sound wave blower.
¾ Steam blower is conventional method, safety,

reliablity.
¾ General steam blower parameter:

steam pressure: 0.8-3.5Mpa
steam temperature: 300-350℃

TPRI
harrow state steam blower

TPRI

Steam blower

TPRI

6.Clear ash method¾ Sound wave blower is developed in recently

year,already much application example.
¾ Technic principle: send low frequency and highenergy sound wave, bring libration power, clear
ash on equipment.
¾ characteristic:(1)prophase invest low; price low;(2)installation cost low;(3)running cost low;(4)maintenance cost low.

TPRI

Sound wave blower installation location

Sound wave blower outside reactor

Sound wave blower effect scope

Sound wave blower inside reactor

TPRI

6.Clear ash method¾ Suggestion for clear ash method:(1)When ash is not nuch on catalyst surface, steam blower
and sound wave blower effect is equal; suggest first choicesound wave, then steam.
(2)When ash is much on catalyst surface, experience
indicate steam blower is more availablity.
¾ Sound wave blower mainly prevent ash sediment.
¾ Blower manner is determined by given power

plant.

TPRI

7.Summary¾ SCR techonlogy is primary coal fired power plants

boiler flue gas deNOX.
¾ When used low NOX burn, SNCR, NOX letconcentration doesn’t satisfy request, SCR
equipment shall be install.
¾ SCR equipment shall be first install in importantarea, economy upgrowth area and landscape area.

TPRI

7.Summary¾ Reducant suggestion:¾ Big power plants boiler use anhydrous ammonia

when anhydrous ammonia wastage is much;deposited erea of anhydrous ammonia isconsidered danger work erea. If want safety,
uses urea.
¾ For small power plants boiler, suggest using

ammonia water liquid. Second suggest urea.

TPRI

7.Summary¾ SCR catalyst choice suggestion:

consider coal characteristic, flue gas characteristic,ash characteristic, N, S, microelement, CaO、
As2O3、ash viscosity, ash fine etc parameter.
¾ New built power plants, SCR reactor suggest highash location.
¾ Old power plants is also to the best high ash
location.
¾ If only condition permission, no need byposs.

TPRI

7.Summary¾ The key of SCR engineering design is

optimisation flue gas and NOX mixing.
¾ Conventional AIG, improvement product.

TPRI

7.Summary¾ Blower ash manner:

steam blower and sound wave blower.

TPRI

Thank you！
zhangqiang@tpri.com.cn;

Day 3 Wednesday 17 October 2007
Session 9: Flue Gas Cleaning Technology

Speech 5 US
Why select Air Monitor technology for total airflow measure?

Mr. David Dunn
Asia-Pacific Sales Manager
Air Monitor Corporation
USWhy select Air Monitor Technology
for measuring total air flow?

AIR MONITOR CORPORATION

4-20031

Why do you need accurate airflow datafor operating Pulverized Fuel Boilers
z
z

z

z
z
z

Can raise the combustion stability, reduce coal surging,
reduce LOI。
Resolve unequal air distribution in the boiler, insufficient
oxygen which leads to boiler explosions and otherproblems
Using accurate airflow can help to maintain the fireball in
the ideal location in the boiler, this can reduce problems
created by flame eroding boiler walls
Optimized air distribution reduces slagging &corrosion
Helps to insure optimized air and coal ratios & increase
boiler efficiency
Most stable and economic method for reducing NOx

AIR MONITOR CORPORATION

2

Importance of accurate airflow for CFB Boilers
Accurate airflow data helps with the maintenance of
bed at the proper high and reduces erosion of boiler
walls and airflow velocity
z Aids in control of boiler temperature maintenancez Helps to correct unequal air supply. For CFBs
control of Primary, Secondary, Tertiary Air is
importantz Optimized airflow help to resolve slagging andcorrosionz Help to insure air supply appropriate for changes inoperating conditionsz

AIR MONITOR CORPORATION

3

Challenges of Airflow Measurement inIndustrial Applications
 Airflow is a process variable capable of rapid and dramatic changes in

the matter of a few seconds
 Extremes of velocity profile stratification and angularity are encountered Very limited straight runs of ductwork available, with airflow

measurement frequently an after thought.
 The airflow is often hot, particulate laden, abrasive and occasionallycorrosive.
 Airflow data must be accurate in order to correctly respond tochanges in boiler load

AIR MONITOR CORPORATION

4

Need For Multi-Point Measurement
 Few installations have enough straight run available Two examples of different velocity profiles in the same duct at different

rates of total airflow.

AIR MONITOR CORPORATION

5

Need For Multi-Point Measurement

Velocity profile at the 1.5 diameter location
when the mean velocity was 26 m/s
AIR MONITOR CORPORATION

6

Need For Multi-Point Measurement

Velocity profile at the 9 diameter location
when the mean velocity was 26 m/s
AIR MONITOR CORPORATION

7

Need For Multi-Point Measurement

Velocity profile at the 14 diameter location
when the mean velocity was 26 m/s
AIR MONITOR CORPORATION

8Need For Multi-Point Measurement

Velocity profile at the 14 diameter location
when the mean velocity was 11 m/s
AIR MONITOR CORPORATION

9Accurate Multi-Point Flow Measurement
 Measurement accuracy depends on:

Available straight run, degree ofswirl, alignment of probes, experience of technicians, and steady state
conditions during test.

AIR MONITOR CORPORATION

10International Airflow Measurement
Standards（Air Monitor conforms to international standards）

AIR MONITOR CORPORATION

11

Pitot-Fechheimer Probe

AIR MONITOR CORPORATION

12VOLU-probe/SS

AIR MONITOR CORPORATION

13

PA – Double Ended Ball Mill
(Primary air used to transport coal to mill – grinder)

Two PA ducts per mill. 3 air
Measurement probes.

PA comes up from here and splits to two ducts above

Hoosier Energy
AIR MONITOR CORPORATION

14

Internally Mounted Probe Array

Florida Power & Light – Riviera Beach
AIR MONITOR CORPORATION

15

Secondary Airflow Measurement

AIR MONITOR CORPORATION

Delmarva Power & Light – Edgemoor Station

16

Partitioned Windbox
Airfoils Replaced with VOLU-probe/SS

Removed Airfoil
Test
Ports
VOLU-probe/SS
Windbox Wall

AIR MONITOR CORPORATION

17

Fujian Putian Meizhouwan Power Plant
Secondary Air Measurement

AIR MONITOR CORPORATION

18

Overfire Air “Scooped” from SA Duct

Atlantic Electric
AIR MONITOR CORPORATION

19

VOLU-probe
Minimum Installation Requirements

AIR MONITOR CORPORATION

20CA Station

AIR MONITOR CORPORATION

21

Combustion Airflow Station

AIR MONITOR CORPORATION

22

Raymond Bowl Mill – Tempering Air Inlet

Pepco Morgantown
AIR MONITOR CORPORATION

23

CA Station
Minimum Installation Requirements

AIR MONITOR CORPORATION

24

VELTRON II（Accuracy to span of 0.01 in WC/ 2 M/Sec 400
Ft/Min)

AIR MONITOR CORPORATION

25

CAMS – Combustion Airflow Management System

AIR MONITOR CORPORATION

26

Multi-CAMS Systems

AIR MONITOR CORPORATION

27

Babcock and Wilcox Early Version Dual
Zone Burner, Final Version and Test
Mockup

AIR MONITOR CORPORATION

28

IBAM-O
Measuring device for Dual Zone Burner

AIR MONITOR CORPORATION

29

IBAM as installed in BPI (Riley)burner

AIR MONITOR CORPORATION

30

IBAM
Individual Burner Airflow Measurement

AIR MONITOR CORPORATION

31

STACK-probe

AIR MONITOR CORPORATION

32

MASS-tron/CEM

AIR MONITOR CORPORATION

33

Accurate airflow data important for efficiency
Accurate Airflow data can have a major impact on energy efficiency
Optimum level usually about 2-4% excess oxygen but conventional airflow
accuracy too inaccurate to deliver appropriate amount of air

AIR MONITOR CORPORATION

34

American Methods for removing NOx
Combustion controls is the first choice due to low cost of
reduction

AIR MONITOR CORPORATION

35

Air supply has a major impact on NOx(This slide shows impact on thermal NOx)AIR MONITOR CORPORATION

36

“Smart Burn”NOx reduction at
ML Kapp Unit 2 U.S. Power Plant

AIR MONITOR CORPORATION

37

Air Monitor U.S. Market Share

AIR MONITOR CORPORATION

38ABB Literature

AIR MONITOR CORPORATION

39ABB Literature

AIR MONITOR CORPORATION

40

ABB Literature

AIR MONITOR CORPORATION

41

Thank You！

www.airmonitor.com
dunndavid@126.com
AIR MONITOR CORPORATION

42

Day 3 Wednesday 17 October 2007

Session 10:
Power Plant Automation andInformation Technologies

Day 3 Wednesday 17 October 2007
Session 10: Power Plant Automation and Information Technologies

Speech 1 PR China
Supervisory Information System at Power Plant Level (SIS) andIts Development

Mr. Yang Dong
Deputy Director
Power Plant Maintenance Optimization and Software Department
Thermal Power Research Institute (TPRI)PR China

TPRI
YangDong
Mr. Yang Dong, born in 1969, is currently a research scientist serving as Vice
Director in the Department of Optimization Overhaul and Software Technologies in
Xi’an Thermotechnical Institute. He graduated from National University of Defense
Technology in Computer Science and Application. In June, 1999, he obtained
Master’s degree in Computer Systems in Xi’an Jiaotong University. He has worked
in Xi’an Thermotechnical Institute since 1990, engaging in research in association
with automation and information in the process of coal based power generation. He
has participated in and presided over several key projects of the National ElectricPower Corporation and some are at ministerial level. He has won a second prize of
China’s Science-technology Award, 3 first and second prizes of Science-technology
Award at provincial or ministerial level, 7 first prizes of Science-technology
Achievements Award in Xi’an Thermotechnical Institute. Up till now, he has
published nearly 20 articles in academic journals.

1

TPRI
Supervisory Information System at Plant Level（SIS）and Development
By
Yang Dong
THERMAL POWER RESEARCH INSTITUTE
Oct. 15, 2007
2

TPRI

OutlineIntroduction of SIS
 Application benefit
 Function extension
 Summary & prospect

3

TPRI
1、Introduction

In 1992, Advanced Manufacturing Research (AMR）put
forward three-tiered integrated model for processenterprise on the basis of plenty of investigation, namely
control level, execution level and planning level.

Each level has its corresponding control/management
system and software.
control level-----〉DCS、SCADA system

execution level -----〉MES system

planning level

ERP system-----〉4

TPRI
In the middle and latter half of the 1990s, process enterprises ofinternationally advanced countries began to develop towards
informatization of production process and power plants in China
followed the trend.

In positioning the connotation of production process
informatization of process enterprise, research organization in theworld came up with the concept of manufacturing execution
system（MES）and established production process
informatization mode for enterprises.

In the same period, Chinese power industry proposed the conceptof plant level supervisory Information system（SIS） in light of its
own characteristics and formed informatization mode of plant levelproduction process “SIS+MIS”
5

TPRI

2、Connotation of SIS“SIS is a real time management and supervisory information
system for production process, serving the overall optimizationof the whole plant production process”
1）Belonging to the scope of plant production process automation
2）Building a platform of a unified plant process real time andhistorical database3）Building a bridge of integration between production management
and process control for the whole plant4）Tapping the potential of main and auxiliary equipments andrealizing overall optimization of production process for the whole
6
plant

TPRI
3、Investment value of SIS
1、An information highway
Connecting many process control systems and terminating
information island.
2、A huge database
Storing long-term and valuable operation data of the plant.
3、A production information portal
A unified platform of process information development
and application.

7

TPRI
4、A “Power generation cost checklist”
Showing on line power generation cost at any time

5、 An “on line economy analyzer”
Accurately analyzing reasons for generation cost increase
and minimizing operation cost with operation optimization guide6、An “equipment health monitor”
Providing reliable technical data for equipment life
management and optimal maintenance decision-making

8

TPRI

4、Positioning of SIS

SIS versus DCS
Difference in service scope ： plant-oriented —— unit-oriented
Difference in main function ： operation optimization —— operation control

SIS versus MIS
Difference in main function ：operation overall optimization —— enterprise management information
Real time and storage mode requirement：high and time sequence —— low and relational
Safety reliability：

high —— low

Reasonable SIS configuration makes plant automationlevel more scientificProcess control automation ( DCS )＋ operation overall optimization ( SIS )＋management information automation( MIS )

9

TPRI

Position of SIS

GroupGrouplevel
levelproduction
production
information
informationnetwork
network

SIS

DCS

PLC
Unit #1~#N

Technology supporting
centerMIS(ERP)

NCS

group
group
production
production
information
information
platform
platform

plant
plant
production
production
informatio
informatio
nnplatform
platform

unit
unit
production
production
informatio
informatio
nnplatform
platform

10

TPRI

5、Component of SIS
Computer and network platform
Basis of hardware. Configuration directly influences performance, safety
and stability of the system.

Real time/historical database
Crucial part ,including database and application development environment.
Database should have high real time performance and realize massive storage
by data compression technology. It is desirable for development environment
to have a platform easy to learn and use for software designers and has richinformation display method and development interface.

Function software for overall optimization
Core and soul. Quality and implementation of application function module
determine the realization of the goal of serving production process overall
optimization of the whole plant and benefit of energy saving and consumption
reduction.

11

TPRI

Typical hardware configuration of SIS

12

TPRI

6、Main application function

Extension function
software module
Basic function
software module

Webmonitoring
monitoringWeb
operation
operation
diagnosis
diagnosis

failurefailureunitlife
lifemanagement
management
unit

loadoptimal
optimaldistribution
distribution
load

process
information
process
information
statisticsand
andanalysis
analysisstatistics
operation optimizationandandoperation
optimization
operationguide
guide
operation
economic index
index analysis
analysis
economic
anddiagnosis
diagnosis
andprocess
process

plant level and unit
unit level
level
plant
level
and
performancecalculation
calculation
performance
production
production
monitoring
monitoring

SIS real time／historical database platform

13

TPRI

7、Developmental milestones of SIS
1）In 1997, the concept of SIS was born in China.
2）In 1998, Ministry of Electric Power officially approved of the construction of
SIS in pilot plant.
3）In 2002, application of SIS was listed in Technical Code for the design ofFossil-fired power plant.
4）In early 2002, State Power Corporation entrusted TPRI to research anddevelop SIS.
5）In Jan. 2005, TPRI-SIS developed by TPRI passed national technicalappraisal and Specification for SIS at Plant Level Fossil-fuel Power Plant
was issued.
6）From 2005，power plant SIS moved into fast track of development.
7）In Feb. 2007, TPRI SIS project obtained the 2nd prize of National Award for
Science and Technology Progress.
14

TPRI

Certificate of TPRI-SIS software
product and copyright

15

TPRI

Certificate

16

TPRI

Outline Introduction of SIS

Application benefit
 Function extension
 Summary & prospect

17

TPRI

1、Economic benefit of energy saving
and consumption reduction
This part of benefit is mainly realized by economical evaluation of on line
operation thermal system of SIS and optimal software, including functions such asunit level and plant level performance calculation, energy-loss analysis, operation
optimization guide and load distribution.
Direct return derived from the construction of SIS depends on 1)the degreeof professionalism in the development on SIS platform of economical evaluationand optimal software; 2)application level in the plant.
At least average equivalent coal consumption for power generation can belowered by 0.5g/(kW·h)～1.5g/(kW·h)through engineering practice and SIS
application.
18

TPRI

1) Energy saving benefit of operation optimization of
circulating water system

For example, circulating pumps of 4X300MW unitof a power plant has made high/low speed retrofit.
There are 3 operation modes for circulating
pump:single pump with low speed operation,
single pump with high speed operation anddouble pump with high speed operation.

By following switchingregulation of operation
optimization of circulating
pump in SIS, annual condenser
vacuum value can be increased
by 0.5kPa and coalconsumption reduced by 1.0
g/kWh. Each year the period of
circulating pump operating withlow speed can be extended by 1
month and 1.58 million kWhpower can be saved. The
economic benefit is quiteconsiderable.
19

TPRI

Aim of turbine operation optimization module in SIS：
(1) Determining dividing point of constant pressure operation mode andsliding pressure operation；(2) Economy comparison between constant and sliding pressure mode；(3) Determining optimal operation mode of the unit with various loads.

20

TPRI

2) Energy saving benefit of turbine operation optimization
Energy Consumption of Unit＃1

Coal consumption rate forpower supply
Heat rate of turbine
Temperature at the inlet of
auto main steam valve
Pressure at the inlet of auto
main steam valve
Efficiency of highpressure cylinder
Inlet steam flow of feedpump
Constant－sliding－constant operation

Optimal valve（slidingpressure）

Actual value(constant)

Energyconsumption

336.18346.3210.14

8532.848695.436.40

538.00538.03

-0.04

14.81

16.46

-2.50

81.67

78.80

3.34

33.69

39.87

1.79
2.63

e.g. Coal consumption rate for power supply of a 300MW unit can be
decreased by 2.63g/kwh merely by adopting constant－sliding－constantpressure operation.

21

TPRI

3) Energy saving benefit of boiler operation optimization
Optimal operation mode

Conventional operation mode
Optimalvalue

Actualvalue

Energyconsumption

Coal
consumption
rate for power
supplyOptimalvalue

Actual value

Energyconsumption

334.51336.03

1.53

Coal consumption
rate for power
supply334.43340.51

6.08

Boiler efficiency

92.34

91.88

1.48

Boiler efficiency

92.76

92.67

0.29

Oxygen content influe gas

5.29

6.08

1.11

Oxygen content
in flue gas

5.15

5.36

0.29

Temperature of fluegas

128.31125.65-0.44

Temperature offlue gas126.84122.44-0.79

Carbon in fly ash

1.46

1.95

0.81

Carbon in fly
ash

1.48

1.94

0.79

By means of boiler operation optimization adjustment, energy consumption of oxygen content influe gas decreases by 0.82 g/kWh. Energy consumption of temperature of flue gas lowers by 0.35
g/kWh and that of carbon in fly ash by 0.02 g/kWh.based on an overall consideration of the above
items, boiler operation optimization drops by 1.19 g/kWh in total.
22

TPRI
4)Energy saving benefit in other aspects
4.1 operation optimization module of feed pump set
Operation optimization of feed pump is to determine optimal operation modeof feed pump set according to load, operation mode of main equipment andefficiency and steam consumption characteristic of feed pump.

With operation optimization module of feed pump set in SIS,
economy of the unit can be increased by 0.4%～0.65％.

23

TPRI
4.2 Operation optimization module of heat regenerative system
Currently, main operation optimization measures of heat regenerative system
are:（1）Follow air heat resistance change in heater and empty promptly；（2）Follow change in effective heat-transfer area and adjust water level inheater promptly.

With performance calculation for heater and monitoring of water level in
SIS, heat consumption can be lowered by 18kJ / kWh throughoptimization of operation parameter for regenerative system.

24

TPRI

2、Management benefit
This part of benefit mainly comes from increase of management quality andsafety level of enterprise.Classification management of enterprise technical andeconomical index in SIS can help to realize modernization, fineness and highefficiency of production management.

Management benefit can be realized by such functions as on line unit thermal
test, report management, unit life management, condition-based inspection andmaintenance guide, comprehensive inquiry and index management, operation
analysis and production report, reliability management and technical supervision
management.
25

TPRI
At present, there isn’t a unified method to make an overall evaluation for
management benefit of SIS. Merely in terms of manpower cost, material cost, test
cost and maintenance cost saved for enterprise. 1-5 million cost can be savedannually for the power plant.

If considerations are given for aspects of increasing safety, prevention of major
equipment destruction or unnecessary unplanned repair and shutdown, theeconomy may be better.

26

TPRI
3、Overall benefit of data integration
Informatization stimulates industrialization. From the strategic perspective ofstrengthening enterprise competitiveness, power generation enterprises will
surly speed up digitization and informatization.
SIS is an important link and basis of realizing digitization and informatization.
It serves as indispensable information platform and bridge, which is of greatsignificance for realizing and gaining overall benefit of digitization power plant.
SIS is rich in valuable digital resources of enterprise. If we can takeadvantage of this resource, there will be greater room for potential anddevelopment, leading to more overall benefit.
27

TPRI

Outline Introduction of SIS
 Application benefit

Function extension
 Summary & prospect

28

TPRI

1、 Increasingly wide coverage of unit type1）300~600MW subcritical units
Shi zuishan, Huang Shi, Han Cheng No2 Power Plant, Song Yu, Zhong Ning2）600MW supercritical units
Qin Bei, Shan Tou, Yang Luo, Lu Zhou, Luo Huang

3）600~1000MW USC units
Yu Huan 4×1000MW, Ying Kou phase II 2×600MW

4）CFB units
Chi Feng, Ji Ning, Bai Yanghe5）Combined cycle units
Bei Jing No3 Cogeneration Plant
29

TPRI
2、More comprehensive and finer data analysis“Equipment
condition
detection andstatistics”-----Providing auto
recording, analytical
calculation andstatistical functionsof data incommissioning andoperation period

30

TPRI

Summary of analog equipment performance

31

TPRI
3、Integration of life calculation and risk-based
analysis technology
On line following of equipment condition to prevent tube explosion and crack
caused by overtemperature and aging with the aim of reducing unplanned
outage period of the unit.
System evaluation object：Superheater
ReheaterHigh temperature
headerMain steam pipe
Reheat steam pipe
Water wall
economizer
Turbine rotor

32

TPRI
System evaluation parameter：
Residual life,
pressure,equivalent temperature；
Main functions：zEquipment information
management
zCondition-based on line
monitoring and evaluation
zOver temperature
inspection and statistics
zOperation check
zOperation history inquiryzReport generation andprinting
33

TPRI
4、Integration of condition-based maintenancetechnology for auxiliary equipment

We consider condition-based maintenance for auxiliary
equipment in 2 aspects:(1) Maintenance of restoration of equipment economical operation(2) Maintenance of equipment part failure

34

TPRI
1) Maintenance of restoration ofequipment economical operationa) Operation condition analysis of air andgas system
Avoid operating in stall region throughmonitoring of operation efficiency ofauxiliary equipmentb) Operation condition analysis ofpump set system
Performance parameter of pump set canbe got by analysis and calculation.
Comparison between performanceparameter and design parameter can bemade and reasons for performance
deficiency can be analyzed. Suggestion of
Methods and steps for operation
adjustment can be made.

35

TPRI
2) Maintenance of equipment part failure
Characteristics reflecting part condition may be selected by monitoring
characteristic parameter of equipment. Analytical result of thecharacteristic can serve as basis for maintenance.
Diagnosis objects：a) main feed pump, booster pump,
circulating pump, condensate pumpb) asynchronous motor, induction motorc) induced draft fan, forced draft fan,primary fan, mill fand) coal mill
36

TPRI

5、Integration of on line reliability and benchmarking
management technology
Reliability management system is used for calculation, statistics, analysis andinquiry of reliability index of unit and equipment in the plant. The system online
acquires start-stop change of equipment. Equipment condition is filled manuallyand reliability index is automatically collected, calculated and generated.
Conventional reliability index includes：
9
9
9
9
9
9

Automatically record start-stop time and times of unit (including main
auxiliary equipments)；
Unplanned (forced)outage time and times of the unit (including main
auxiliary equipments) ；Equivalent utilization hours and equivalent availability of the unit (including
main auxiliary equipments) ；Forced outage rate of the unit；
Load rate of the unit；
Addition of customized index.
37

TPRI

Benchmarking management to realize
index assessment and target

Compare the domestically advanced level value of main index, the best index value
in the plant history, planning value, stage assessment index value and present
statistical value. The result is shown in “spider chart” or “bar graph”.
38

TPRI

6、Integration of management technology of online
technology supervision
Design target：
Nine supervision items are to be managed with a series of new supervision
technology and method, ultimately enhancing reliability, economy andenvironmental friendliness of power equipment.
(1) Target management realizing equipment on line monitoring andinspection(2) On line evaluation and risk-based management realizing equipment
present condition(3) Aging trend analysis and life management
39

TPRI
Plant on line technology supervision
management system

Metal supervision
Boiler supervision
I&C supervision
Chemistry supervision
Relay protection supervision
Electric measurement
supervisionHigh voltage supervision
Environmental protection
supervision
Energy saving supervisionuser management

40

TPRI

7、Plant operation on line real time supervisorysystem at group level

Development of SIS at group application level with the target of：
9 Knowing actual operation condition and operation efficiency of theunits under the group and at the plant；
9 Prompt judgment and comparison of main operation performanceindex of the units；
9 Obtaining operation optimization guidance and technical support；
9 Tapping production potential of the plant, further improving overall
operation performance index of the plant and group；
9 Raising technology management and on line supervision level ofpower generation group.
41

TPRI

Group side platform

Plant side platform
数据计算

数据接收
数据采集

数据库
数据发布

机组N
厂端发布

实时 历/史数据库

机组1

数据
计算

直接显示
厂端用户

数据计算
机组1
技术资料数据库
数据采集

数据库

机组N
厂端发布

远程专
家系统

厂端用户

Group Company WAN

Technical service &support42

TPRI
Main functions
menu

Displaying realreal-time data of 8 main performance parameter of all the power plants
plantsCompany
overview

1. Displaying of performance parameter of Huaneng Power International and administration company
according to management mode；
mode；
2. There are 6 regions in addition to Shandong region according to geographic location.

Plant level analysis

Displaying main plant level performance parameters of different power plants based on an option

Plant levelcomparison

Comparing main plant level performance parameter of different plants
plantsUnit analysis

Comparing main unit performance parameter of different unit according
according to an option

Unit comparison

Comparing main plant level performance parameter of different units
units

Performancemonitoring

1. Displaying plant level performance diagram of the plant
2. Displaying performance diagram of the unit
3. Displaying performance diagram of boiler and turbine

Trend analysis

Have access to historical data of all the parameters

Report browsing

1. Displaying daily and monthly aveg.
aveg. of main performance parameters in company overview andregion overview
2. Displaying daily and monthly aveg.
aveg. Of main performance parameters at plant level
3. Displaying daily and monthly aveg.
aveg. Of main performance parameters at uint level

Communication
condition

Providing communication condition of data
43

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Power generation overview of CHNG

44

TPRIIndex comparison of operating units of CHNG

45

TPRI

Operation Performance at Plant level

46

TPRI

Outline Introduction of SIS
 Application benefit
 Function extension

Summary & prospect
47

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1、Construction of SIS marks that power plant has entered a
new period of production informatizaiton construction

SIS will fundamentally change the production process
informatization of the plant. It cannot produce instant results as
DCS. With wide application, its benefit will become noticeable.
Therefore, we should take a long term view to give plant
informatization due position. Facts have proved that power
plants whose leaders attach great importance to SIS are those
apply SIS well.SIS as well as its maintenance work should
receive attention.
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TPRI
2、Taking full advantage of modern production information
technology is an effective means to strengthen operation
management and operation optimization
SIS independently developed by Chinese has enteredapplication stage. The technology takes the lead worldwide with
noticeable economic and environmental protection benefit. SIS isgradually becoming necessary technology support for plant
production information management and application.
Unit production operation information system at group level
developed on the basis of SIS system has been put into operationin HPI. In the future, unit operation information and optimization
system at regional level will be developed.
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TPRI

3、Focusing on construction of digitization power plant tospeed up informatization process of power group1）Digitization plant came into existence in recent years. However, there isn’t
a unified identifier for this concept. Everyone thinks in his way.
2）We hold the view that this philosophy should be born in mind at design
stage. It should be implemented progressively according to technology andconditions available.
3）Currently, development and application of SIS in Chinese plant areproceeding smoothly. Nevertheless, development and application ofequipment and maintenance management system are not going well, whose
significance and application benefit are not inferior to SIS. Thus, this part is ofpressing concerns.
4）Power plant digitization is the basis of power group digitization while
power group digitization is the head of power plant digitization. It isreasonable that power group should make a unified plan for power plant
digitization.

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TPRI
Thanks!

Yang Dong

029-82102527 13609249029
yangdong@tpri.com.cn

51Day 3 Wednesday 17 October 2007
Session 10: Power Plant Automation and Information Technologies

Speech 2 PR China
Development of New Technology and Informationalization in Power
Plant Equipment Management

Mr. Zhong Jindong
Deputy Director General
Weihai Power Plant
PR China

TPRI

钟金东
工学硕士、高级工程师。长期从事火力发电厂生产技术、设备管理
工作，历任华能威海电厂检修部副主任、热化部主任、副总工程师、
厂长助理、副厂长。获得的荣誉：热控系统现场状态检修及专家系
统山东省科技进步三等奖；大型调峰机组燃烧控制系统的研究获山
东电力科技进步奖；发电机组深度调峰研究获中电联三等奖，山东
省科学技术协会优秀论文二等奖，荣获山东电机工程学会优秀论文二、三等奖两项，现任山东电机工程学会会员，山东电机工程学会
热工控制专业委员会会员。

电站设备管理技术发展与信息化
The Development of New Technology andInformationization of Equipment Management in Power Plant

演讲人：钟金东Lecturer: Jindong Zhong华能威海电厂、西安热工研究院
Huaneng Weihai Power Plant, Xi’an Thermal Power Research Institute2007年10月
OCT, 2007

TPRI

目录 Contents
 背景 Background 优化检修技术发展 The recent development of the plantmaintenance optimization technology 设备管理信息化进展 The recent development of the equipment
management technology

 TPRI-EMS系统 The TPRI-EMS System

TPRI

背景 Background 电力企业是资产密集型企业，检修费用占电力成本的比例相当大，除燃料成本外，设备运行维护检修费用成为电力企业主要的成本支出，并且随机组的大型化而不断
升高； Electric power enterprise is assets intensified enterprise. Maintenanceexpense occupies a great part of electric power cost. Besides fuel cost,
The equipment maintenance expense becomes the main cost
disbursement, and rises unceasingly while the unit gets larger.

TPRI

背景 Background 研究表明，在电厂的检修成本中，有30%的检修工作是浪费的，检修工作经常是最大的可以控制的费用，检修节省的费用可直接转变成利润； Study indicates that, in the plant maintenance cost, 30% of the work isuseless. Maintenance expense is always the maximal cost that can becontrolled. So, the economized cost turns into profit directly.

TPRI

背景 Background 电厂陆续建成的系统缺乏统一的技术规划，造成企业内软件系统泛滥，数据重复录入，大量企业信息无法及时共享，更谈不上企业数据挖掘和决策支持，产生了大量
的信息孤岛。
 The system that electric power plant establishes in succession is short of
the unified technology plan. It brings about various software systems,
data recorded repeatedly, lots of enterprise information can’t be sharedin time, not to mention the data mining of enterprise and decision
support. Many information islands come out.

TPRI

背景 Background 积极采用先进检修管理方法和检修技术是降低检修成本的有效途径，优化检修技术作为有效降低检修成本、增
加机组安全可靠性的有效手段已逐步在国内发电领域开
展起来 ； advanced maintenance method and technology Adopted can reduce thecost effectively. The plant maintenance optimization technology is
gradually developing in the domestic electric power generation field, as
it can reduce cost and increase unit’s reliability.

TPRI

背景 Background 作为优化检修技术平台的 CMMS（Computer
Maintenance Management System）即计算机化的检修管
理系统是实施这一先进技术的可靠载体和工具。
 As the platform of maintenance optimization technology, CMMS
（Computer Maintenance Management System）is a reliable carrier
and tool to carry out this advanced technology.

TPRI

CMMS的出现 The appearance of CMMS
 到目前为止，国外有正式发布CMMS产品的
公司多达几百家，国内较熟悉的有：IFS、
SAP、Datastream、BFS＋＋和MAXIMO等。
 At present, there are hundreds overseas companies
announced CMMS formally. We are familiar with: IFS,
SAP, Datastream, BFS＋＋,MAXIMO and so on.

 但现有的CMMS产品存在实施成功率低，应
用效果差等问题。
 CMMS in existence has some drawback, for example: low
success rate, poor application effect, etc.

TPRI

CMMS的作用 The purpose of CMMS
将检修管理的所有项目纳入计算机管理，实现：Brings all the projects of the maintenance management into computer
maintenance management, makes:
企业检修策略的最佳选择 the best choice of enterprise maintenancestrategy检修部门的有机协调 coordination among maintenance departments检修资源的优化使用 optimal use of maintenance resource检修计划和检修过程的合理控制 reasonable control of maintenance plan andprocess降低库存积压 reduce overstock——CMMS最终实现设备的合理使用和降低检修成本
CMMS finally makes use of equipment reasonably and reduces maintenancecost effectively.

CMMS的总体功能TPRIThe primary functions of CMMS

功能一：
Function 1:

 将电厂日常运行维护（故障与缺陷处理等）的工作计
算机化，利用先进的信息手段支持电厂检修，将电厂
的运行、维护及检修工作进一步规范化。
 Computerize the plant daily maintenance (deal withfault and defect). Support the plant maintenance withadvanced information technology. Further standardize
the operation and maintenance.

CMMS的总体功能TPRIThe primary functions of CMMS

功能二：
Fucntion 2:
 加强电厂的技术管理，提高设备可用性，保障电厂的生产质量及安全，优化运行检修过程中的人力、物力、备品备件费用，提高电厂设备寿命。
 strengthens the technology management of plant, raises
equipment availability, ensures production quality andsafety, optimizes manpower, material resources andspare parts cost, extends equipment life.

CMMS的总体功能TPRIThe primary functions of CMMS

功能三：
Function 3:
 通过基于周期、事件和测量等的预防性维护手段提高电厂维护检修中的预见性和计划性，将企业员工尤其是生产人员从大量的事后处理的“救火模式”下解放出来。
 By the Preventive Maintenance means based on thetime, event and measurement, improves the previsionand plan of maintenance, avoid mass after-treatment.

CMMS的总体功能TPRIThe primary functions of CMMS

功能四：
Function 4: 通过基于周期、将电厂内的运行、检修、生技、计划、物资、文档资料管理等部门以电厂的运行、维护检修为主线协调统一起来，更好地实现事前计划、事中控制、事后报告与分析改进。
 Gives first place to the plant’s operation and maintenance,
coordinate the departments of operation,
maintenance,technology,plan,material,data management,
etc. Makes plan, control, report and analysis better.

CMMS的基本模块TPRI

The primary functions of CMMS
 基础数据 basic data module 设备台帐管理模块 equipment account management module 缺陷管理模块 defect management module 工单（工作票）管理模块 work order management module 项目管理模块 item management module 预防性维护管理模块 Preventive Maintenance management module 库存管理模块 inventory management module

TPRI

设备管理新技术发展
The recent development of the equipment management technology设备状态监测技术； condition monitoring technology of equipment设备状态评估技术； condition assessment technology of equipment
检修决策分析技术； maintenance strategy analysis technology
设备检修管理技术。 Maintenance management technology
通过检修管理流程（P-Plan，计划；D-Do，执行；C-Check，检
查；A-Action，改进）的精细分析和优化， 力求在保持机组安全
可靠性的同时有效降低检修成本。
By the analysis and optimization of PDCA （P-Plan, D-Do, C-Check,
A-Action）, reduces maintenance cost while keep the unit availability
effectively.

优化检修技术新发展TPRI

The recent development of the plant maintenance optimization technology 寿命分析：LA 可靠性分析：RCM
 风险分析：RBM
 根源失效分析：RCA

TPRI

RCM－Reliability Centered Maintenance 根据设备的可靠性状况，以最少的检修资源
消耗，运用逻辑决断分析法确定所需的检修
内容、检修类型、检修间隔期和检修级别，制定出合理的预防性检修计划，从而达到优化检修的目的。
 Based on the equipment’s reliability condition, with the least cost of
maintenance, ensure the content, type, period and class of maintenanceby logical analysis, thus attain the purpose of maintenance optimization .

TPRI

RBM－Risk based maintenance 结合故障可能性和故障后果的分析，建立设备基本风险大小的优先排序方法。根据排序来设计控制（减少或修理）设备风险 analyses the failure probability and failure consequence, establishes
preferential sort method of equipment risk class. Control the risk ofequipment, according to the sort.
 重要度分析技术；importance analysis technology 风险分析技术； risk analysis technology
风险管理技术；risk management technology
设备检修策略分析技术；Equipment maintenance strategy
analysis technology

probability



Fault consequence检修决策分析技术TPRI

The maintenance strategy analysis technology
检修决策分析技术是研究设备检修方法，检修内容和检修周期的技术。
maintenance strategy analysis is the technology that study the methods,
contents and period of maintenance.

 目前，我国火电厂广泛采用的基于时间周期的预防性计划检修模式，该模式在预防设备故障起到了重要作用，但也存在着严重的缺陷，如临时性检修频繁、检修不足或检修过剩、盲目检修等，使火电厂每年在设备检修方面耗资巨大。
 At present，power plants in our country adopt the Preventive Maintenancebased on time period broadly. This maintenance have played a great role inpreventing equipment failure, but has great defects, for example, temporary
maintenance frequently, maintenance redundancy or maintenance insufficient,maintenance blindly and so on, which make power plant blowing the expense atenormous at the aspect of equipment maintenance every year.

检修决策分析技术TPRI

The maintenance strategy analysis technology
 随着检修技术的发展，越来越多的设备采用状态检修技术，该技术根据先进的状态监视和诊断技术提供的设备状态信息，判断设备的异常，预知设备的故障，
在故障发生前进行检修，即根据设备的健康状态来安排检修计划，实施设备检修。
 With the development of maintenance technology, Condition-based
Maintenance (CBM) has been applied in more and more power plants.
Based on the condition information of equipment provided by advanced
condition monitoring and diagnosis technology, the abnormal condition
and fault can be diagnosis timely. CBM is to repair equipment before
fault appears and establish maintenance schedule based on theequipment condition.

检修决策分析技术的步骤TPRI

The procedure of maintenance strategy analysis technology(Risk-based analysis of important equipment)(make maintenance schedule of unimportant equipment)(make maintenance schedule of important equipment)

一、设备重要度分析

TPRI

The analysis of the equipment importance按照： 设备安全影响； 环境影响； 法规影响； 经济性影响等主要条件进行设备重要度评定，将设备分为高重要度设备和低重要度设备，高重要度设备进行风险分析，根据风险分析结果制定检修策略和检修模式，非重要设备直接进行检修模式分析。
The rank of equipment importance is decided by:
 The influence of safety
 The influence of environment
 The influence of law and regulation
 The influence of economy
The equipment will be divided into important equipment and unimportantequipment. The important equipment will be analysis by Risk-based analysis
method based on which maintenance strategy and mode is to be established.

二、设备定性风险分析开始(start)The qualitative risk analysis of equipments 定性风险分析关键是确定设备故障发生可能性和故障后果 The key of qualitative risk analysis is todetermined the probability and effect ofequipment fault.
 故障发生可能性的确定主要依据： 检修历史评价 故障历史评价 它厂故障评价 寿命评估结果

高重要度设备

Important equipment
故障预想

Fault assumption

故障发生可能性故障后果Probability of Fault

Consequence of Fault
评定风险级别

 The probability of equipment fault will be
determined based on the factor : Evaluation of maintenance history
 Evaluation of fault history
 Evaluation of fault history in other plant Life assessment

TPRI

Assess risk rank
制定维修策略Make maintenance plan维修后风险等 If the risk rank is级是否合理 reasonable after

no 否

maintenance?

yes 是
end

结束

二、设备定性风险分析开始(start)The qualitative risk analysis of equipments
 故障后果的确定主要考虑：

安全、法规、环境的影响
对发电生产的影响设备检修费用设备检修时间

TPRI

高重要度设备

Important equipment
故障预想

Fault assumption
故障发生可能性故障后果 The consequence of equipment Probability of Fault Consequence of Fault
fault should be determined based评定风险级别
on the factor:
 The influence of safety, law andenvironment
 The influence of production toplant Maintenance cost
 Maintenance period

Assess risk rank
制定维修策略Make maintenance plan维修后风险等 If the risk rank is级是否合理 reasonable after

no 否

maintenance?

yes 是
end

结束

受热面半定量风险评估

开始

TPRI

(start)The semi-quantitative risk analysis of the boiler heating
surface
高重要度设备

 根据受热面的特点，选取了三种
方法确定受热面的失效可能性： 失效统计法
 老化指标评级法 设计寿命损耗率法

Important equipment
故障预想

Fault assumption
故障发生可能性

故障后果 Based on the characteristic of boiler
Probability of Fault Consequence of Fault
heating surface , three methods has been评定风险级别
chosen to determined the probability ofthe equipment failure:
Assess risk rank Failure statistic method
制定维修策略
 Aging index method
Make maintenance plan Method of attrition rate of designed
life
no 否
维修后风险等 If the risk rank is
级是否合理

yes 是
end

结束

reasonable after
maintenance?

受热面半定量风险评估评估TPRI

The semi-quantitative risk analysis of the boiler heating surface

水冷壁、省煤器减薄风险分析The risk-based maintenance of thinning mode for waterwalls andeconomizer
再热器、过热器蠕变风险分析
The risk-based maintenance of creep mode for reheater and superheaterrisk management of
thinning mode受热面减薄风险管理

Calculate thinningrate

水冷壁当前厚度分布

省煤器当前厚度分布计算减薄速率计算减薄速率Display thicknessof waterwalls in 显示下个检修周期内
水冷壁壁厚分布next outage period
Make maintenanceplan

Risk managementof creep mode

Current thickness

Current thicknessof waterwalls受热面蠕变风险管理给出检修方案of economizer
Calculate thinning
rate

Display thickness显示下个检修周期内 of economizer in
省煤器壁厚分布 next outage period

给出检修方案

Make maintenanceplan

通过金相确定材
料老化级别

assess aging rankby metallography确定受热面的风险级别assess risk rank确定受热面的检
修方案

Make maintenanceplan设备检修模式分析

TPRI

The analysis of the equipment maintenance mode 对于重要设备，按照设备状态监测的可行性、有效性和必要性进行分析，优先推荐采用状态检修模式；按照定期检修可行性
和有效性进行分析，尽可能采用定期检修模式；对没有适合而有效的预防性检修技术的重要设备及非重要设备，采用事故检
修模式。
 For important equipment, the condition-based maintenance will berecommended firstly based on the analysis of the feasibility,
effectivity and necessity of condition monitoring. The time-based
maintenance (TBM) will be recommended possibly based on theanalysis of feasibility and effectivity of TBM. For other importantequipments and unimportant equipments , breakdown maintenancecan be chosen.

设备管理信息化的进展

TPRI

The development of the equipment management informationization设备管理的广度和深度加大equipment management extended and deepened.



新的检修管理模式的融入The appearance of new maintenance management mode软件结构的变化

The development of software framework用户化工作流程customized workflow

设备管理信息化的进展

TPRI

The development of the equipment management informationization
设备管理的广度和深度加大:equipment management extended and deepened:现代化企业经营要求有效地利用企业的全部资源资产（如生产设备、厂房设施、交通工具和仪器仪表等），在保证安全、经济运行和环保的同时，
最大限度地提高效益、降低检在修成本。
CMMSÆEAM（Enterprise Asset Management，企业资产管理） ，实现资产的全生命周期管理。
It is necessary to make use of the total resource and assert (equipment, utility, vehicle andinstrument) for Modern enterprise management. Based on the guarantee of safety, economy andenvironment protection, modern enterprise should increase benefit and reduce maintenance cost possibly.
the lifecycle management of asset has been realized by CMMSÆEAM （ Enterprise AssetManagement)设备管理信息化的进展

TPRI

The development of the equipment management informationization
EAM的应用:主要应用于资产密集型企业对高价值固定资产的维护、保养、跟踪等信息管理。
EAM系统把眼光放向管理一个公司的资产，以达到这些资产使用的最优化、降低企业运行维护成本为目标，以优化企业检修资源为核心，通过信息化手段，合理
安排检修计划及相关资源与活动，从而提高企业的经济效益和企业的市场竞争力。
Application of EAM:
EAM has been applied mainly in the information management of maintenance, repair and track of highvalue fixed asset.
EAM will manage the whole asset of the enterprise , optimize the use of asset and aims to reduce the costof operation and maintenance. In the end, EAM will help enterprise raising their profit and competitivness byplanning the maintenance, resource and activity reasonably.

设备管理信息化的进展

TPRI

The development of the equipment management informationization

EAM的功能:基础数据 (basic data module)设备台帐管理模块 (equipment
account management module)

库存管理模块 (inventory
management module)运行管理 (operation management)

工单（工作票）管理模块 (work 财务管理 （finance management）

order management module)预防性维护管理模(Preventive
Maintenance management module)

缺陷管理模块 (defect management
module)项目管理模块 item management
module人力资源管理 (human resource
management)设备管理信息化的进展

TPRI

The development of the equipment management informationization
新的检修管理模式的融入:
the new mode of maintenance management integrated into equipment
management：
20世纪80年代后半期，随着基于风险的检修（Risk-Based
Maintenance，RBM）和寿命周期检修(Life Cycle Maintenance ,LCM))
等技术的发展和应用，为设备开展优化检修提供了新的方向。
In the latter half of 1980s, the development and application of Risk-Based
Maintenance (RBM) and Life Cycle Maintenance (LCM) technology guide a
new direction to carry out optimized maintenance.
同时，设备故障机理的研究和监测诊断技术进步，PDM/CBM Æ 设备
资产管理系统(Plant Asset Management，PAM)。
At the same time, the study of fault mechanism and the technology ofmonitoring and diagnosis has been improved .

设备管理信息化的进展

TPRI

The development of the equipment management informationization

PAM的主要功能:The main function of PAM: 编制点检计划
 make spot inspection schedule 设备在线监视、诊断 On-line monitoring and diagnosis of equipment 离线点检
 Off-line spot inspection 报警应答 Alarm response 校正管理 Calibration management设备管理信息化的进展

TPRI

The development of the equipment management informationization
EAM与PAM的功能对比:
Function comparison of
EAM and PAM:

设备管理信息化的进展

TPRI

The development of the equipment management informationization软件结构的变化:进入21世纪后，随着互联网的在全球的风靡，给传统的设备检修管理
和服务也带来了巨大的变化，为了跟上这一潮流，各CMMS/EAM厂商开发了基于Internet的B/S产品，以满足用户更加多样化的信息共享需要。
the change of software
framework:
In the 21st century, thepopular internet change thetradition maintenancemanagement and service
greatly. Many CMMS/EAM
supplier developed
production based on B/S inorder to satisfy the morevariable need of sharing
information .

设备管理信息化的进展

TPRI

The development of the equipment management informationization

系统集成和业务重组面向服务的体系架构（Service-Oriented
Architecture，SOA )是一种软件系统架构，它满足了市场对软件互联互通，复用和业务流程重组的需要。当业务流程改变时，SOA可以更好的支持业务的变化。同时，SOA采用构
件、Web服务以及XML技术，使得不同应用系统之间的集成、
数据交换以及业务重组成为可能。
Service-Oriented Architecture (SOA) is a kind of software system framework, It
has satisfied the marketplace needs that software should be interconnected、intercommunicated、Multiplexed and business process re-organized. When businessprocess changes, SOA can be better to support the change of business. At the sametime, on account of SOA adopting a component, Web services and XML technology,
data exchange and business re-organized can be possible.

设备管理信息化的进展

TPRI

The development of the equipment management informationization

用户化工作流程 :Customized work process:电厂的检修管理流程和组织机构是与电厂所采用的管理体系相配套
的。
Maintenance management process andorganization in Power plant fit toadministrative system adopted by power
plant.

TPRI

TPRI-EMS系统
Thermal Power Research Institute Equipment Management System 自1998年起，热工研究院开始系统的研究优化检修技术，特别在检修管理评价、检修策略分析、设备状态监测、设备管理技术等
方面取得明显进展，相继开发了一系列优化检修技术与系统，为开发国内自主知识产权的设备管理系统（TPRI-EMS, Thermal
Power Research Institute Equipment Management System）打下良好
基础。
From 1998, Thermal Power Research Institute (TPRI) begins to study the plantmaintenance optimization technology, especially in maintenance management
assessment、maintenance strategy analysis、 condition monitoring ofequipment, equipment management technology etc. TPRI has make a rapid
progress in the study and developed a series of maintenance optimization
technology and system, that is fine basis to develop the equipment management
having the independent Intellectual property （TPRI-EMS, Thermal Power
Research Institute Equipment Management System）.

TPRI

TPRI-EMS系统
Thermal Power Research Institute Equipment Management System

 TPRI-EMS 设备管理系统将基于先进的设备管
理理念，特别是风险管理、寿命管理、标竿管理等设备管理新思想，变革设备管理体制，完善设备管理流程，建立灵活、合理的检修决策
支持技术体系。
TPRI-EMS is based on advanced equipment management notion, such as risk
management, life management, benchmarking , etc. TPRI-EMS makes therevolution of equipment management system, perfect equipment management
flow, and build flexible and proper maintenance management decision-making
technology system

TPRI

TPRI-EMS系统的特点
The character of TPRI-EMS TPRI-EMS设备管理系统是为适应中国火电厂管理流程与设备特点而专门设计的管理软件，其主要使用对象是电厂领导（管理层）、策划人员（技术层）、运行、检
修人员（执行层）等设备相关部门人员，体现国内电厂设备管理习惯和检修人员思维定式；
 TPRI-EMS is a special software that is fit to domestic management
process and the character of equipment. It is used manly by leaders ofplant (management), planning personal (technology), operator,
maintenance personal, etc, and reflects the habit of equipment
management and thinking formulary of employee in domestic power
plant.

TPRI

TPRI-EMS系统的特点
The character of TPRI-EMS
 采用优化检修的理念，建立设备状态信息集成的动态管理数据库
平台；
 Adopt the notion of optimization maintenance, and build the dynamic
management database platform centralized by equipment status.
 融入热工院优化检修相关研究成果，特别是风险寿命管理技术，检修策略分析与评估技术，适用于电厂采用预防性检修、预知性检修、故障检修、改进性检修等多种检修方式。开发出能够体现
企业内控管理要求的火电厂设备管理系统。
 The related research achievements are embedded into TPRI-EMS,
especial the risk management technology, maintenance strategy analysis
and evaluation technology that help maintenance personal chose
Preventive Maintenance、Predictive Maintenance 、malfunction
maintenance and many other modes of maintenance. TPRI-EMS
Develops equipment management system embodied the demands ofinternal control in enterprise.

TPRI

TPRI-EMS系统的特点
The character of TPRI-EMS TPRI-EMS设备管理系统可实现检修策略分析、检修计划制订、检修过程管理、检修质量控制、检修效果评价、检修记录存储查询等电厂设备管理完整流程的标准化管理，推进设备管理信息化水平。
TPRI-EMS equipment management system can realize maintenance strategy
analysis, maintenance planning working-out, maintenance process management,
maintenance quality control, maintenance effect evaluation, maintenance record
storage and the standardization management of the equipment management
complete flow and push forward equipment management informationizationlevel.

TPRI

TPRI-EMS系统
Thermal Power Research Institute Equipment Management System

设备管理系统包括：Equipment management system including： 设备状态集成平台（PAM）；
 Plant asset management platform; 检修决策分析平台； Maintenance strategy analysis platform; 检修管理实施平台（EAM）；
 Enterprise asset management platform;

三个子系统 。
Including three subsystems.

TPRI

TPRI-EMS系统
Thermal Power Research Institute Equipment Management System 设备信息管理子系统： Equipment information management subsystem 用户管理 The user management ； 公共信息管理 Common information management ； 设备台帐管理 Equipment account management ； 设备状态管理（设备状态评估） Equipment statusmanagement； 缺陷管理模块 defect management module； 报表模块 Report forms management module ； 接口管理模块 Interface management module ；TPRI

TPRI-EMS系统
Thermal Power Research Institute Equipment Management System 检修决策分析子系统： Maintenance strategy analysis subsystem 设备状态评估与检修策略分析管理模块； Equipment status estimation and maintenance strategy analysis
management module 检修计划模块
maintenance plan module 。
 检修管理子系统： maintenance management subsystem 检修工单/项目/工作票管理模块；
The work order / item/ work permit management module； 检修库存管理模块maintenance stock management module ； 检修资源管理模块
maintenance resource management module ；TPRI

TPRI-EMS系统
Thermal Power Research Institute Equipment Management System

设备信息管理子系统
Equipment information management subsystem 设备历史状态台帐信息是设备检修管理的基础，通过科学及合理的组织设备层次结构，可以更方便地跟踪、分析各级设备的运行及检修情况、缺陷管理及其费用等。通过设备在线、离线
等数据的集成，将实现设备老化趋势分析预测功能，实现设备
当前状态的及时评估。
Equipment history status record is the basis of the equipment maintenancemanagement. By organizing equipment levels and structures rationally, it canbe more easily to track and analyze the running and maintenance condition of
the various levels equipment、defect and cost and so on. By integrating
equipment data of online and offline, TPRI-EMS will realize the forecast ofequipment aging trend and the equipment present state in time.

TPRI

TPRI-EMS系统
Thermal Power Research Institute Equipment Management System
检修决策分析子系统
Maintenance strategy analysis subsystem检修决策分析技术就是研究设备检修方法，检修内容和检修周期的技术。
目前，我国火电厂广泛采用的基于时间周期的预防性计划检修模式，该模
式在预防设备故障起到了重要作用，但也存在着严重的缺陷，如临时性检
修频繁、检修不足或检修过剩、盲目检修等，使火电厂每年在设备检修方面耗资巨大。随着检修技术的发展，越来越多的设备采用状态检修技术，该技术根据设备状态和分析诊断结果安排检修时间和项目，并主动实施检修。在我国现阶段火电厂检修制度中状态检修将和计划检修制度长期共存。

Maintenance strategy analysis is the technology studying equipment maintenancemethod、content and period. At present，power plants in our country adopt broadly thepreventive maintenance based on time period. This maintenance have played a great rolein preventing equipment failure, but has defects, for example, temporary maintenancefrequently, maintenance redundancy or maintenance insufficient, maintenance blindlyand so on, which make power plant blowing the expense at enormous at the aspect ofequipment maintenance every year. With development of maintenance technology, more
and more equipments uses condition based maintenance technology, which makes
arrangement for maintenance time and the project according to equipment state andanalysis result and makes initiative maintenance. In China’s present stage, condition
based maintenance and plan maintenance will be the long-term coexistence in power
plants.

TPRI

TPRI-EMS系统
Thermal Power Research Institute Equipment Management System
设备管理子系统

Equipment management subsystem

注重把检修工作纳入企业以成本为中心的管理工作中，实现企业检修策略
的最佳选择、检修部门的有机协调、检修资源的优化使用及检修计划和检修过程的合理控制等，真正使设备以更高的精度、速度、安全性和经济性
投入有效的生产应用，创造预期的经济效益。

Equipment management subsystem pay attention to maintenancemanagement work brought into the cost administration of enterprise. It
realizes that the enterprise chooses the best maintenance strategy, makes themaintenance branches being in harmony, optimizes the maintenanceresource, controls maintenance plan and process reasonably and so on. It
makes equipment to be managed with higher accuracy, speed, safety andeconomy and earn the expected profit.

TPRI

设备检修管理基本流程The process of the equipment maintenance management
策略 / 起因

strategy/cause缺陷单

Defect sheet
工作计划Work Plan

工单

工单领料

项目管理

Order

Draw material

Project management工单分项

操作票 / 隔离单(Operating order/Isolation sheet)
Order Subitem
执行

日期

信号
执行

Date

SignalImplement

Implement恢复

Recover
工作完成

工作完成

Completed

Completed

工作验收

Check

TPRI

小结 Conclusion
 采用先进检修管理方法和检修技术是降低检修成本的有效途径； It is an effective way to adopt advanced maintenance management
method and maintenance technology to reduce the cost of maintenance; RCM、RBM分析技术已成为有效降低检修成本、增加机组安全可靠性的有效手段。
 RCM and RBM analysis technology has already become means to
reduce cost of maintenance effectively and increase safety andreliability of unit.

TPRI

小结 Conclusions

新的设备管理系统具有以下特点：

New equipment maintenance management has the characters below:
 基于中国火电厂设备现状和管理特色，推行先进的风险寿命管理思想；
 Based on the equipment reality and characters of management in domestic power
plant, push the advanced thought of risk and life management; 设备状态动态管理数据库平台，完善设备趋势分析技术； Be provided with the database platform of the dynamic management of equipment
status, perfect equipment trend analysis technology; RBM分析、检修策略分析、检修周期评价等技术为基础的设备检修计划优化； The equipment maintenance plan optimization based on RBM analysis、
maintenance strategy analysis、maintenance period assessment technology and soon 实现可视化、易操作、可灵活配置业务流程的设备管理系统；Realize the equipment maintenance management of visualization , easy to handle and allocate
business process flexibly;

便于进一步扩展到实现集团级的设备管理；Easy to take a further step to realize Corp. level equipment management;

Thank you ! 谢谢!

Day 3 Wednesday 17 October 2007
Session 10: Power Plant Automation and Information Technologies

Speech 3 PR China
HPI Fuel Centralized Payment Management System

Mr. Zhao Anxiang
Huaneng Power International Inc
PR China赵安详
HPI
Fuel Centralized Payment
Management System华能国际电力股份有限公司处长，高级工程师。毕业于华北电力大学热能动力专业。1986年—1993年在电力部电力规划设计总院从事火电厂勘察设计计划管理及火电厂前期规划管理工作。1993
年至今在华能国际电力股份有限公司先后从事火电厂前期项目规
划管理及公司燃料供应、燃料结算及电厂燃料管理工作，是公司
燃料集中结算系统项目开发组成员之一。

Key Points

An Introduction of Huaneng Power International, Inc.
Business Challenge Faced by HuanengPower International, Inc.
 Management Strategy in Coping with
Challenge
 Realization of Management Objectives
with the Assistance of IT
 Application and Development of FuelCentralized Payment System
 Observations and Experiences

Business Challenges HPI is Facing










Intense market competition, as the big 5 generation groups, various
local power investment companies and large coal produces havebeen competing to invest in coal-fired power plants in recent years
Since 2004, steaming coal has been in short supply due to strong
demand from the power sector. There is an overall shortage in coaltransportation capacity, including rail, sea and river transport
HPI’s 2004 Annual Report stated that:
During the reporting period, the Company’s gross margin
declined by 22.8% yoy due to significant increases in coal pricein 2004 and the resulting fuel cost escalation.
In December 2004, NDRC issued a circular on the establishment of
the Coal-electricity Price Linkage Mechanism, under which power
enterprises have to absorb 30% of coal price increase
Per statistics to date, fuel accounts for over 60% of overall
production cost







Huaneng Power International, Inc. was founded on June 30, 1994.
As one of the largest power producers in China, it is engaged in thedevelopment, construction and operation of power plants throughout
China
At the end of January 2007, the attributable installed capacity of HPIreached 28,187MW
HPI is the largest listed power producer in China and is listed in
Shanghai, Hong Kong and New YorkIts service area include Northeast, North China, Northwest, East
China, Central China and South China grids. The Company whollyowns 17 power plants, has controlling interests in 13 powercompanies and minority interests in 4 others
It owns China’s first domestic made 600MW supercritical generating
unit; its Dalian Plant is the first in China to receive “First-rate
Thermal Power Plant” award; Huaneng Yuhuan Power Plant, whichis still under construction, will be install with the largest coal-fired
unit in China

Fuel Supply is of Great Significant to Business
GrowthEnsureSupplyRaise
OutputIncrease
Revenue

Earnings
GrowthMaterialize Delivery
Stabilize Price
Ensure Transportation

Control
Price

ReduceFuel Cost

Cut
Cost

© 2003-2005 Microsoft Corporation. All rights reserved.
This presentation is for informational purposes only. Microsoft makes no warranties, express or implied, in this summary.

Fuel Management Strategy with “ThreeCentralization” at the CoreManagement Strategy of “Starting with theMost Important Link ”

To actively cope with market challenge, theCompany formulated a fuel management
strategy with “Three Centralization” at the CoreCentralized
Procurement

Centralized
Transportation

Centralized
Settlement

“Manual Type” Centralized Payment Face
Challenges







Brief Introduction of “Fuel Centralized
Payment” System

Data transmission is based on fax, which makes it
difficult for fuel department and finance department at
HQ to exchange information and work in synch
Fax and telephone messages can not be effectively
converted to structured data for storage, therefore
inquiry and analysis are inconvenientApproval process is not secured and tracked by IT
system, therefore it is not under strict control
There is disconnect between payment approval,
accounting and payment due to paper-based informationexchange. It is difficult to track a problem if discrepancy
occursSystem Structure

Starting with “centralized settlement”, through standardized
settlement approval process, fuel procurement becomes moretransparent, and gradually supplier and contract management
become more intensive
Mutually responsive and supportive with finance management
guidelines of “capital concentration, centralizing revenue andexpenditure, and duel track processing of revenue and expenditure”“Fuel Expense” accounts for 60%-70% of “centralized payment”.
Keeping adequate control of fuel payment is of great significance toenhancing capital efficiency and rationalizing production cost
“Centralized Payment” has been adopted by HPI since 2004. The
system operated for a year using fax plus manual process, during
which extensive experience was gained and foundation was laid forenhancing the level of sophistication by means of IT

ReportCentralized Payment Process is built around reviews
and on the basis of work flow platform. The process iscustom-made and traceable
Process review and business data control andconversion are integrated and incorporates a series ofprocess automatizations such as “Automatic Budgeting
Control”
Through settlement management, the process can betraced back upstream to strengthen supplier, contractand fuel procurement control
Data exchange with Financial Accounting System and
Huaneng Finance Internet Banking System is realized toensure automatic transfer of raw data between different
systems and minimize the possibility of error in datatransmission

System Function Structure

Flow Control

Business
Business
Document
Document
Input
Input

Review
Review
ResultResultAccounting
SystemBusiness Rule Engine

Encrypted
Transfer

Huaneng
Finance
Internet
Banking© 2003-2005 Microsoft Corporation. All rights reserved.
This presentation is for informational purposes only. Microsoft makes no warranties, express or implied, in this summary.

Process can be Clearly Tracked

Data Collection and Analysis
Storing review process and business objects structurally will provide thebasis for in-depth analysis of problems and enhanced macro-control of
suppliers and contracts, and will be conducive to the formulation of cost
control strategy on fuel procurement from an overall point of view

Advantages of the SystemBusiness Review Process combines fuel management at
plant and at headquarters as well as financial
department review into one, operates on a uniform andtraceable platform, thus enhancing the efficiency of interregional and inter-departmental information exchangeFuel management becomes more standardized due tothe strengthening of “Centralized Payment Review” andenhancement of business control

Integrating business review, accounting and internet
banking system makes the tracking of the whole
payment process possible and ensures the consistencyof key financial information beyond the boundary of IT
systemThe System is a Boost to the Company’s
Fuel Management







The System is Boost to the Company’s
Finance Management

All expenses associated with fuel, such as coal, oil, transportation,
pre-payment, etc. have been incorporated into one uniform control
system under which all expenditures related to fuel are undereffective control
By strengthening control on supplier admittance and contract review,
cost exposure is brought under control from the beginning. At
present 33 power plants operated by HPI use the system for
supplier and contract submission. So far over 1800 suppliers andmore than1400 contracts have been approved
Same stringent approval process applies to the alteration of fuelprocurement contract to further strengthen internal control
On the basis of finalized data, supplier ranking by supplied volume,
settled volume and contract fulfillment rate, etc., and othercomprehensive statistical functions can be realized and will serve as
the basis for macro-management activities such as supplierclassification and increasing contract supply

An Extension of “Centralized Payment
Management” SystemIntegrating “Centralized Payment review” with capital management,
accounting management and payment management can enhancethe efficiency of payment. In 2006 the Company realized over 7000
centralized payments and outlays totaling RMB30 billion.



HPI initially adopted “Centralized Payment Management” in its
wholly-owned plants. The system performed well and now is being
extended to and having its experience shared by power plants
controlled or operated by HPI

The system realized automatic control of capital budgeting thus
making capital budgeting more standardizedCapital management staff can check the amount of capital pending
review through the system, therefore they can make more scientificprojections over capital payment and formulate more accurate plans
with respect to capital arrangement and borrowing, resulting inenhanced capital efficiency and effective control on financial
expense in borrowing activities

The experience gained from fuel centralized payment has been
applied in other business areas. Currently “Centralized Payment
Management” has become a comprehensive platform for capital
payment review, capital expenditures for construction, production,
renovation, financing, etc. have all been incorporated into thisplatform
Data generated by centralized payment system is provided to “DataCenter” and enterprise portal, which are under construction, andserves as the source of raw data for the statistical analysis of theCompany production and operation

The system realized pre-payment quota and offsetting management
thus enhanced the level of control on pre-payment, reduced financial
risk and improved capital efficiency© 2003-2005 Microsoft Corporation. All rights reserved.
This presentation is for informational purposes only. Microsoft makes no warranties, express or implied, in this summary.

System Construction Experiences andObservationsThe building of IT system shall closely follow corporate businessdevelopment, identify the key areas of business development andthe role of IT system, so as to establish system building objectives
with an view on the value of such system
The basic condition for success is to properly formulate system
function structure and technical structure in view of the needs ofvarious level of customers and in accordance with different
expectations of customers at operating level, medium managementlevel and senior management level

Thank you！

The key to successful application is to have effective coordination,
unified goal and work in concert between IT department andbusiness department, and receive support from senior management© 2003-2005 Microsoft Corporation. All rights reserved.
This presentation is for informational purposes only. Microsoft makes no warranties, express or implied, in this summary.

Day 3 Wednesday 17 October 2007
Session 10: Power Plant Automation and Information Technologies

Speech 4 PR China
Foundation of Digital Power Plant is Fieldbus Control System

Mr. Yan Yuping
Scientist
Chief Engineer
Department of Fieldbus and Control Technology
Thermal Power Research Institute (TPRI)PR China

TPRI

YanYuping

Mr. Yan Yuping got his Master‘s degree in Power Plant Engineering in
TPRI in 1987. He is currently serving as the Chief Engineer ofAutomation Center of TPRI. His research interests include automation
technologies such as PLC, DCS applied in coal-fired power plants andthe research, development and application of Fieldbus Control System.
As a prize winner of a few China’s Electrical Science & Technology
Awards, he has published more than 20 articles in academic journals.

TPRI

数字化电厂的基础－现场总线控制系统(FCS)Foundation of Digital Power Plant—Fieldbus Control System

西安热工研究院有限公司
Xi’an Thermal Power Research Institute

TPRI

数字化是电厂自动化发展的趋势
Digital Trend of Power Plant Automation


The power plant management is progressing
towards modernization of energy saving,environment conservancy, efficiency.
Need substantive field information.



The foundation of the plant information is thefield device digitalization.
Digital device provides the reliable status anddiagnoses data.

IT and network technology make the field
digitalization possible.
The fieldbus intelligent devices and the network
connection are the equipment of the digitalization

数字化电厂的模型结构
Structure of Digital Power Plant

TPRI



Three layers for the basic structure of the digital
power plant in ours points, though which is not a
standard defination.

1.

Layer of Decision and Management.:MIS ( Management
Information system ), DSS ( Decision support system )2.

Layer of combining control with management: SIS( Supervisory Information System for Plant Level ), SIMU
( Simulation system )3.

Layer of process control and monitor: Automatic control
system for Unit & periphery shop (DCS、FCS、Fieldbus
divice)数字化电厂的模型结构

TPRI

Structure model of Digital Power Plant
Layer of Decision andManagement: MIS , DSS
Layer of combining Control withManagement :SIS , SIMU

Layer of Process Control andmonitor :DCS, FCS, Fieldbus
divice

TPRI

数字化电厂的关键环节Key of Digital Power Plant
The essence of the plant digitalization is the practicaland efficient function of SIS

– Bridge between the basic control layer and the highmanagement layer.
–The software modules such as the real-time analysis,
optimization, status evaluation, and so on.
– Plenty of data from field devices。
 The foundation of power plant digitalization is Field-

bus technology–Traditional DCS & PLC can not meet the requirement of
information.
–Fieldbus has the whole digital and bidirectional transmitting
pattern, without the cable limit;–Intelligent Field-bus device can provide plentiful status anddiagnosis and other useful digital information.

TPRI现场总线控制系统在国内电厂的应用
Application of FCS in China Power Plant
Fieldbus technology has been applied partly indomestic power plants–The Profibus-DP regulating valves in 200MW unitof the XINHAI power plant.
–The Motor controllers with Profibus-DP interface(SIMOCODE) in 330MW unit and periphery shopsof the XIAGANG power plant (total 346).
–The FF fieldbus instruments in 1000MW unit of
the ZOUXIAN power plant (more than 130)

TPRI

现场总线控制系统在国内电厂的应用
Application of FCS in China Power Plant
 Thermal Power Research Institute (TPRI )dedicates to the research and application of
FCS technology in power plant＊Study of theory：book and paper＊ Study in Fieldbus laboratory ：Profibus，FF＊ Product: diagnosis & management software
based on fieldbus data
＊ Design & integrate FCS engineering project.

TPRI现场总线控制系统在国内电厂的应用
Application of FCS in China Power Plant
 The firstly whole set of FCS for power plant

had been established in Huaneng Yuhuan
power plant in China.
TPRI had developed the water treatment FCS with theProfibus technology, including HMI 、PLC、ProfibusDP&PA network、fieldbus instruments 、diagnosis
software. And the FCS system has been operatingsafely and steadily since Feb. 2006.

现场总线控制系统（FCS）概貌
Overview of FCS Network

TPRI

TPRI

现场DP和PA支路的网络结构Network of Local DP & PA BranchTPRI现场总线智能仪表及设备
Fieldbus Intellective Meter & Device
Profibus-PA instruments– DP/PA LINK output single PA branch，rate 31.25k
bps；– PA branch link pressure, level transducer

TPRI现场总线智能仪表及设备
Fieldbus Intellective Meter & Device
 Motor control & protect

unit （SIMOCODE)– DP interface equipment ；– Programmable start up,
stop and protect functions ;– Current, status, diagnosis
infomation；– Remote check, setparameters

TPRI现场总线智能仪表及设备
Fieldbus Intellective Meter & DeviceDigital control unit（ET200x)& Pneumatic valves– DP interface ；– DI model for position feedback of valve ；TPRI现场总线智能仪表及设备
Fieldbus Intellective Meter & DeviceUltrasonic levelmeter

DP interface meterFrequency converter

DP interface device实时诊断信息和设备管理

TPRIReal-time Diagnostic message &Device management


PDM Software
PDM software was used for PA meters remotemonitor, diagnosis, etc, with an increased efficiency
The application area of the PDM is extended to the
management of SIMOCODE, which save investment
and satisfy requirement of SIMOCODE
management.

TPRI

自主开发中文界面的诊断和管理软件

Develop Independently on Chinese Interface
Diagnosis & Management Software
 TPRI had developed Chinese interface diagnosis andmanagement software for fieldbus device independently .

Transmitter information

Ultrasonic level transmitter information

自主开发中文界面的诊断和管理软件

TPRI

Independent Develop on Chinese Interface
Diagnosis & Management Software
Motor run information

Electric maintenance information

中文界面的诊断和管理软件

TPRI

Diagnosis & Management Software on
Chinese Interface
Diagnosis & management display on operator station by network中文界面的诊断和管理软件

TPRI

Diagnosis & Management Software on
Chinese Interface
Diagnosis & management display on operator station by meters锅炉补给水FCS系统经济性分析

TPRI

Economy Analysis of Water Treatment FCS
Compare between FCS and conventional PLC system
Boiler water treatment system I/O were 536,FCS included
490 ； Compare not including HMI system
No.

Item of compearing

PLC(%)

FCS(%)

FCS
Save

1

PLC controller &modules

100

112.6

-12.6

2

Power cables

100

100

0

3

Control cables

100

13.7

86.3

4

Cable bridges

100

49.4

50.6

5

Install for cables

100

13.7

86.3

6

Instruments & devices

100

112.2

-12.2

TPRI

锅炉补给水FCS系统经济性分析
Economy Analysis of Water Treatment FCSCompare result :Direct cost (equipment,material ) save about 7%;
not including the costsaving in the installationand the commissioning
by FCSTPRI

机组控制系统FCS的设计
Design of FCS in Power Unit Control System
Main principia for design unit FCS– Adopt the prevailing fieldbus standard, FF, Profibusand Hart；– DCS is skeleton system inserted the fieldbus module；–The control system involved in the unit safety andprotection configured in DCS, and adopted the Hart
protocol instrument ；–The main control functions are configured in DCS
controllers；– Fielbus diagnosis & management software is important.

There needed enough attention to theengineering risk, the safety, the engineering
phase date and so on. Gain most benefit.

TPRI

机组控制系统FCS的设计
Design of FCS in Power Unit Control System The Brief for Unit FCS

engineering construction– Firstly, confirm the type of the DCS and fieldbus

standard.
– Enough attention to the design of the fieldbus
network.
–The necessary compatibility test between fieldbus
instruments, including the communication and cooperating compatibility.
– The proper fieldbus network specification in alllayers.
– the whole test of the fieldbus network, theinstrumnent, and the control performance before thesite installation.

TPRI

辅助控制系统FCS的设计
Design of FCS in Assistant Control System
 Main principia for design periphery shop FCS– the prevailing fieldbus standard: Profibus and FF.

– PLC is the skeleton inserted the fieldbus
communication module.
–Plenty of fieldbus devices.
– Several independent FCS in the periphery shops,
linked into a central monitor system by Enthernet.
– Fielbus diagnosis & management software isimportant.

TPRI
数字化电厂的生产过程自动化控制系统
Process Automatic Control System of Digital Power Plant

Extensive adopting fieldbus devices makedigital the ground layer of automatic system– With the progress of fieldbus technology, thefieldbus device will meet the requirement of
power plant.
–Much abundant information and data.
–The evidently reduced cost.

TPRI
数字化电厂的生产过程自动化控制系统
Process Automatic Control System of Digital Power Plant

Fieldbus becomes main I/O network–Several main type of fieldbus communication module
can insert into the distributed control station
seamlessly .
–The bidirectional link is carried out between fieldbus
module and fieldbus device.
–The current (voltage) signal can adopt the Hart
protocol if necessary.

TPRI
数字化电厂的生产过程自动化控制系统
Process Automatic Control System of Digital Power Plant
 The advanced performance controller is the core ofcontrol system–Complex control and protect strategy need advanced
performance controller.
–Quick control cycle is 20ms；–fieldbus data integrate with conventional I/O– Status & diagnosis data collecting, treating, transmitting.
 The traditional I/O signal will co-exist with the fieldbus

signal in a rather long time
–The resolving capability SOE is 1ms– The control cycle for over speed protection of turbine is
20ms.
– The signals dealing with important protection require
redundancy or fast acquisition.
–Reduce the cost of dispersed and remote digital signal.

TPRI
数字化电厂的生产过程自动化控制系统
Process Automatic Control System of Digital Power Plant

HMI is similar to DCS, but has more diagnosis &management–Ethernet is main communication network.
– Configuration of fieldbus network, device, remote maintenance,etc.
– Database manage conventional I/O and fieldbus data
together ；– The fieldbus device diagnosis & management software orfunction station
工程师站
操作员站 操作员站 历史站
诊断管理站

彩色打印机

激光打印机

记录打印机

中央控制室

控制站

TPRI
数字化电厂的生产过程自动化控制系统
Process Automatic Control System of Digital Power Plant
The character of the automatic control

system in power plant– The control ideal inherited from the DCS .

–The digital fieldbus device is primary, and theconventional I/O is compatible.
–The integration of DCS control function, fieldbus
diagnosis and management function

It is a new automatic control system thatfieldbus technology infiltrates into
conventional DCS, which is called as FCS(Fieldbus Control System)结 束 语
conclusion

TPRI

The power plant digitalization is some kindsof certain trend of the electric powerindustry. As the Technology Center of the
China Huaneng Group, the TPRI will makemore and more innovation and progress inthe field.

TPRI

谢谢各位专家和朋友！
ThanksDay 3 Wednesday 17 October 2007

APEC Clean Fossil Energy
Technical and Policy Seminar
Harmonious and Sustainable
Coal Power Generation

Closing Session

Day 3 Wednesday 17 October 2007
Closing Session

Seminar Summary

Mr. Jiang Minhua
Director
Thermal Power Chapter (TPC)
Chinese Society for Electrical Engineering (CSEE)
President
Thermal Power Research Institute (TPRI)PR ChinaDay 3 Wednesday 17 October 2007
Closing Session

Closing Remarks

Mr. Scott Smouse
APEC EGCFE Chair
International Coordination Team Leader
National Energy Technology Laboratory (NETL)
Department of Energy (DOE)
USCLOSING REMARKS
Scott M. Smouse, Chair
Expert Group on Clean Fossil Energy
Harmonious and Sustainable Coal Power Generation
APEC Clean Fossil Energy Technology and Policy Seminar
Xi’an, People’s Republic of China
17 October 2007

The theme of this week’s APEC seminar was “Harmonious and Sustainable Coal Power
Generation.” We’ve focused on the some of the challenges that coal faces, not only in the
APEC region, but everywhere that it is produced and used. Over the past 2-½ days, we’veheard from 12 of the 21 APEC member economies, plus India, about their energy situations
and clean coal technology development activities. We’ve reviewed present coal demand andsupply data along with projections from most of the APEC economies that are major
producers and users of coal. We’ve discussed commercial clean coal technologies and next
generation technologies, and touched on the policies and regulatory environments that are inplace in some APEC economies and their implications for deployment of these advanced
technologies. Several economies have told us about their national coal and climate change
strategies.
I think you will all agree that the common message we’ve heard is that today’s technology
continues to reliably power many APEC economies. However, it is becoming increasingly
evident that today’s technology cannot deliver the environmental performance necessary
when hundreds of gigawatts of new power plants will be built in the region to meet future
electricity demand.
The World Bank estimates that 2 billion people – a number that has hardly changed in thepast 20 years – do not have access to basic energy services. As I mentioned in my opening
comments, all forms of energy and energy conservation are needed if we are to bring enoughenergy to those who either have no access to commercial energy or whose supply of energy is
so inadequate or unreliable as to even meet their basic needs.
We should not abandon or discredit any form of energy, including coal. All rhetoric aside,
there is no bad form of energy, only bad ways to use energy.
Energy security and climate change….these two topics are among the most hotly debatedpolitical and social issues being addressed by government, industry, and non-governmentalorganizations around the world, with the full attention of the general public.
In my opening comments, I noted how coal is under attack around the world, and shared withyou some of the recent assaults and setbacks that coal has faced in the APEC region andaround the world. The growing global environmental conscience is demanding more open
dialogue as the decisions made on these issues will significantly impact how energy will be
produced, delivered, used, and priced at all levels of our economies. Sound decisions bygovernment and industry can best be made through open communication involving the local
citizenry.
The general public has made their voice heard that the dialogue on why and how we use coalcannot be between just technologists and policy makers. They are using the full array oftools at their disposal – NGOs, the courts, the media, and the internet – to be a part of that
dialogue.
As I’ve said at past EGCFE seminars, to silence coal’s critics, we face four major challenges:(1) Develop the technologies needed to allow fossil fuels to meet much of the world’s futureenergy needs as cleanly as possible with our ultimate goal being zero emissions,(2) Ensure that the mechanisms exist to move these technologies into the marketplace atcompetitive prices when they are needed,(3) Develop our energy markets in such a manner that electricity, transportation fuels, andother forms of energy can be delivered to end users efficiently and at the lowest possible
price, and lastly,(4) Communicate to policy makers around the world and to the general public that coal cancontinue to reliably power our homes, schools, hospitals, businesses, and industries by using
these new more efficient, cleaner technologies.
We are engaged in the R&D and the full-scale technology demonstrations that will allow us
to transition from a fossil fuel-based world to some as yet to be defined energy future,
however, the reality is that fossil fuels will continue to be the basis of economic growth formany APEC economies for at least several more decades. The APEC region, like the rest of
the world, faces significant challenges in meeting its energy demand without negatively
impacting the environment. The Expert Group will continue to foster communication
throughout the APEC region so that economies can better consider the wide range oftechnical and policy options that are available today, and that will be available in the future,
to allow coal and other fossil fuels to be used as cleanly and efficiently as possible.
From their own background and experiences, each of our speakers over the last 2-½ days
discussed one or more salient issues that will affect the way that coal will be produced andused in the coming years. Each of these presentations contributed to the dialogue on thecomplex technical, political, and business questions that must be answered to secure coal’srole as an energy source in the region. The Expert Group will continue its efforts to help
ensure that some of our more creative ideas make it to the marketplace and become part ofour national strategies and policies. We welcome your comments on how we can better meetyour needs and how we can work together in the future.
In closing, I wish to once again acknowledge the organizations that have supported thisseminar. I want to thank our sponsors, which includes all of the five major Chinese utilities
and the China National Coal Association, Japan’s New Energy and Industrial Technology
Development Organization (NEDO) and the Japanese Committee for Pacific Coal Flow
(JAPAC). We would not be here this week without their support. And we owe a special
thanks to our host, TPRI, who helped make this workshop a success under the leadership of
their President, Mr. Jiang. Also, I want to once more thank Dr. Katsuyoshi Ando of Japan for
all the years of sharing his knowledge and insight with others in the APEC region anddedication to the promoting the clean, efficient production and use of coal throughout theregion.

I thank all of the speakers and chairs for their efforts and taking time out of their busy
schedules to be with us. Lastly, we would all be remiss to not acknowledge the tirelesssupport of the many people that we all see but rarely thank…those who work behind thescenes at events like this one to make them successful, including the local organizing team,the management and staff of the hotel, and many others who’ve done such an outstanding job.
To them, I offer my special thanks.
This week, you heard from a couple of our speakers on a few of the EGCFE’s studies. I
don’t think that these studies, which cover a wide range of technology and policy issues andtopics, get the attention that they deserve, so I would like to take a minute to mention a few ofthem to you.
Over the past few weeks, three new projects have been started. The first of these is a followon project to the study that Jette Findsen of the U.S. consulting firm, Science Applications
International Corporation (SAIC), reviewed on Monday entitled “How Can Environmental
Regulations Promote Clean Coal Technology Adoption in APEC Developing Economies?”
This new project, which will also be managed by Ms. Findsen, will review “Environmental
Monitoring for Coal-Fired Power Plants in Developing Asian APEC Economies.” She told
me that she has made some excellent contacts among the participants here this week and will
be following up with some of you for input into the report.
The other two projects are titled “Lessons Learned in Upgrading and Refurbishing Older
Coal-Fired Power Plants - A Best Practice Guide for Developing APEC Economies” and“Technology Status and Project Development Risks of Advanced Coal Power Generation
Technologies in APEC Developing Economies.” Both of these studies will be conducted by
the U.S. office of the multinational engineering firm, WorleyParsons. The first of these will
prepare a best practice guide for developing APEC economies on upgrading and refurbishing
their older coal plants as part of a series of EGCFE projects focusing on improving theperformance and economics of existing coal-fired power plants in the region. In the second
project, we will look at the development status and project development risks associated withbuilding new coal power plants using new advanced technology, including supercritical andultrasupercritical pulverized coal and IGCC plants, in the region. Improving the performanceof existing coal-fired power plants in the region can significantly reduce coal consumption
and emissions because the existing inventory of power plants in the region totals hundreds ofgigawatts.
In our next project, “Reducing Trade, Regulatory, and Financing Barriers to Accelerate theUptake of Clean Coal Technologies by Developing Economies in the Asia Pacific Region,”
we plan to work with the U.S. Agency for International Development’s ECO-Asia Program
to convene a workshop on harmonizing emissions standards for coal-fired power plants
throughout the region. In our last new project, “Increasing the Knowledge and Awareness ofCarbon Capture and Storage: Capacity Building in the APEC Region,” we hope to hold two
capacity building workshops in China or other developing APEC economy. These
workshops will follow our initial capacity building workshop held in Korea a few years ago,
and China and Mexico over the past year. Yesterday, my colleague, Dr. Frank Mourits ofCanada, gave an overview of the Expert’s Group’s carbon capture and storage activities,
including this new project
Yesterday, during our EGCFE business meeting, we began planning the next Clean Fossil
Energy Technical and Policy Seminar. We haven’t decided on a location yet, so please watch

our web site for more information on this event and for the final reports on the various
projects that I just mentioned along with announcements on other new projects that we areplanning.
In closing, I thank each and every one of you for your active participation in this seminar andhope that you have a safe trip home or wherever you are headed. I look forward to seeing
you at one of our future events.
Thank you.

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