産炭国石炭開発・利用協力事業
平成 22 年度石炭情報交換事業「アジア太平洋石炭セミナー」
報

告 書

平成 23 年 3 月（独）新エネルギー・産業技術総合開発機構
委託先： 神鋼リサーチ株式会社
財団法人石炭エネルギーセンター

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産炭国石炭開発・利用協力事業
平成 22 年度 石炭情報交換事業「アジア太平洋石炭セミナー」
本編

1. 要約 ··································································································· 2
2. 講演概要 ····························································································· 9(1)

開会セッション ············································································· 10① 開会の辞 APEC EGCFE 議長 ..........................................................................10② 来賓挨拶 1 資源ｴﾈﾙｷﾞｰ庁資源・燃料部長........................................................11③ 来賓挨拶 2 麻生福岡県知事 ..............................................................................12④ 特別講演 1 資源ｴﾈﾙｷﾞｰ庁資源・燃料部長.........................................................13⑤ 特別講演 2 IEA ｴﾈﾙｷﾞｰ政策技術局長 ...............................................................13⑥ 特別講演 3 米 DOE 化石燃料局企画環境分析室長 ..........................................14⑦ ｽﾍﾟｼｬﾙﾚﾎﾟｰﾄ 日本ｴﾈﾙｷﾞｰ経済研究所 ................................................................15(2)

セッション 1A APEC ｴｺﾉﾐｰの石炭政策 (i) ········································ 16① 講演１ｶﾅﾀﾞの石炭需給動向...............................................................................16② 講演 2 ﾌｨﾘﾋﾟﾝの石炭政策と CO2 削減 .............................................................17③ 講演 3 韓国の石炭政策と CO2 削減.................................................................18(3)

セッション 1B APEC ｴｺﾉﾐｰの石炭政策 (ii) ······································· 19① 講演１豪州の石炭政策と CO2 削減..................................................................19② 講演 2 ｲﾝﾄﾞﾈｼｱの石炭政策と CO2 削減 ...........................................................20③ 講演 3 ﾀｲの石炭政策と CO2 削減 ....................................................................21(4)

特別講演 4 ｱｼﾞｱにおけるｸﾘｰﾝなｴﾈﾙｷﾞｰ ··············································· 22(5)セッション 2 高効率石炭火力発電技術の普及による CO2 削減(i) ············· 23① 基調講演１APEC 域における環境問題を解決するための日本の役割.............23② 講演 1 中国における USC 技術の導入と課題..................................................24③ 講演 2 韓国における USC 技術の導入と課題 ..................................................25④ 講演 3 日本における高効率石炭火力発電技術の開発による CO2 削減...........26(6)

特別講演 5 高効率石炭火力発電技術への ADB の支援 ·························· 27(7)セッション 3 高効率石炭火力発電技術の普及による CO2 削減(ii) ··········· 28① 講演１IGCC と ICS~日本発世界へ向けた先進的技術~実証実験から実用化へ 28② 講演 2 米国のガス化プログラムの概要 ............................................................29(8)

特別講演 6 GCCSI による CCS 実証試験に向けた支援 ························· 30(9)セッション 4A(i) 低品位炭技術(i) ······················································ 31① 講演１低品位炭の効率的利用に関する開発と調査の紹介 ...............................31② 講演 2 HWT による低品位炭利用技術 .............................................................32③ 講演 3 低品位炭活用における産業化構造........................................................33

(10) セッション 4A(ii) 低品位炭技術(ii) ···················································· 34① 講演１ｲﾝﾄﾞﾈｼｱにおける低品位炭利用 ..............................................................34② 講演 2 二塔式ガス化炉による化学原料ガス製造技術 .....................................35③ 講演 3 低品位炭利用における将来展望 ...........................................................36(11) セッション 4B(i) APEC 域における CCS 開発動向(i) ····························· 37① 講演１日本における CCS 研究開発の現状.......................................................37② 講演 2 ｶﾅﾀﾞにおける CCS 開発概要 ................................................................38③ 講演 3 韓国における CCS ﾌﾟﾛｼﾞｪｸﾄ現状 .........................................................39(12) セッション 4B(ii) APEC 域における CCS 開発動向(ii) ··························· 40① 講演１東芝の CO2 ｷｬﾌﾟﾁｬｰ技術開発動向.........................................................40② 講演 2 台湾における CCS ﾌﾟﾛｼﾞｪｸﾄの現状......................................................41③ 講演 3 東南ｱｼﾞｱにおける天然ｶﾞｽ随伴 CO2 の CCS 可能性調査.....................42④ 講演 4 米国の CCS に関する省庁間ﾀｽｸﾌｫｰｽ....................................................43(13) セッション 5 ﾊﾟﾈﾙﾃﾞｨｽｶｯｼｮﾝ：APEC 域における CO2 削減の方向性········· 44① ﾓﾃﾞﾚｰﾀｰからの提案 ...........................................................................................44② ﾊﾟﾈﾘｽﾄ 1 豪州からの意見 ..................................................................................44③ ﾊﾟﾈﾘｽﾄ 2 米国からの意見 ..................................................................................45④ ﾊﾟﾈﾘｽﾄ 3 ｲﾝﾄﾞﾈｼｱからの意見.............................................................................46⑤ ﾊﾟﾈﾘｽﾄ 4 ｶﾅﾀﾞからの意見 ..................................................................................46⑥ ﾊﾟﾈﾘｽﾄ 5 日本からの意見 ..................................................................................47(14) 閉会の辞 ······················································································ 50
3. テクニカルツアー概要 ··········································································· 51
4. APEC 地域における石炭需給動向····························································· 59(1)

世界の石炭需給動向 ······································································· 60(2)CO2 削減の可能性 ········································································· 66

資

料 集

1.

セミナープログラム ·············································································資料 12.

講演資料 ····························································································資料 8(1) 開会セッション ·············································································資料 9(2) セッション 1A ··············································································資料 94(3) セッション 1B ··············································································資料 155(4) 特別講演 4 ···················································································資料 201(5) セッション 2 ················································································資料 223(6) 特別講演 5 ···················································································資料 306(7) セッション 3 ················································································資料 324(8) 特別講演 6 ···················································································資料 367(9) セッション 4A(i) ···········································································資料 401(10) セッション 4A(ii) ··········································································資料 470(11) セッション 4B(i) ···········································································資料 505(12) セッション 4B(ii) ··········································································資料 577(13) セッション 5 パネルディスカッション················································資料 672(14) 閉会の辞······················································································資料 722

本 編

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１． 要約2

1. 概 要アジア太平洋石炭セミナー（APEC 石炭セミナー）は、日本政府の主唱により始められた APEC 加盟国･地域を中心とする石炭関係の国際会議であり、毎年開催地を替えて官民の石炭関係者を一堂に集め、石炭政策と需給及びクリーン・コール・テクノロジー等についての情報交換を行っている。
アジア太平洋地域においては、近年の経済発展に伴い、石炭需要が増加傾向にあり、今後、当該地域における石炭需給が逼迫することが予想されている。我が国においても、
一次エネルギーの約２割を石炭エネルギーに依存しており、石炭の安定供給確保が重要な課題である。また、地域温暖化問題に対する国際的な関心も益々高まっているところである。
このような中、今年度のセミナーは、第１７回目となるが、1999年の横浜開催以来11年ぶりとなる日本での開催であり、全体テーマを「クリーンコール技術の新たな展開とCO2削減」（NewDevelopments in Clean Coal and CO2 Reduction）と設定し、福岡市にて開催した。
また、海外炭安定供給研究会を設け、アジア太平洋石炭セミナー等における戦略的な情報収集・提供について検討した。
１． 開催日時
平成 22 年 10 月 27(水)～29 日(金)２． 開催場所
福岡県福岡市ヒルトン福岡シーホーク
３． 主催者・後援者等
主催
・ APEC 化石燃料専門家会合グループ(EGCFE=Expert Group on Clean Fossil Energy)
日本
経済産業省(METI)
米国
エネルギー省(DOE)
カナダ
天然資源総局(NRCaN)
豪州
資源エネルギー観光省(DRET)
セミナー事務局
日本
独立行政法人新エネルギー・産業技術総合開発機構(NEDO)
財団法人石炭エネルギーセンター(JCOAL)－アジア太平洋コールフローセンター（JCOAL-JAPAC）
神鋼リサーチ株式会社

後援
・ 日本国経済産業省(METI)・ 米国エネルギー省国立エネルギー技術研究所(NETL=National Energy Technology
Laboratory)
・ カナダ国天然資源総局(NRCaN=Natural Resources Canada)
・ 豪 州 連邦 資源 エ ネル ギー 観光 省 (DRET= Department of Resources, Energy andTourism)
協賛・九州電力株式会社
・電源開発株式会社
・三菱重工株式会社
４． 参加者数等
参加者数：講演者･聴講者あわせて計 269
参加国 ：日本、インドネシア、米国、カナダ、タイ、フィリピン、韓国、中国、

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豪州、台湾（計 10 カ国･地域）、
国際機関：IEA（国際エネルギー機関）、ADB（アジア開発銀行）、
GCCSI（世界 CCS 研究所）（計 3 機関）
５． 内容(1) 全体テーマ“New Developments in Clean Coal and CO2 Reduction Technologies”（クリーンコール技術の新たな展開と CO2 削減）(2) プログラム骨子
2 日間に亘り行われたセミナーでは、各国の石炭及び CO2 削減政策と需給に関しての最新の報告と、クリーン・コール・テクノロジーの発表と意見交換等が行われた。
一日目(10 月 27 日)
Opening Session 開会セッション
Session 1A Coal Policy in the APEC Economies (i)APEC エコノミーにおける石炭政策(i)Session 1B Coal Policy in the APEC Economies (ii)
APEC エコノミーにおける石炭政策(ii)
特別講演 4
Clean Energy in Asia
アジアにおけるクリーンなエネルギー
Session 2
高効率石炭火力発電技術の普及による CO2 削減(i)CO2 Reduction by Diffusion of High-Efficient Coal-Fired
Power Generation (i)特別講演 5
ADB’s Support towards Efficient Coal-Fired Power Generation
高効率石炭火力発電技術に対する ADB の支援
Session 3
高効率石炭火力発電技術の普及による CO2 削減(ii)
CO2 Reduction by Diffusion of High-Efficient Coal-Fired
Power Generation (ii)
二日目(10 月 28 日)
特別講演 6 GCCSI による CCS 実証試験に対する支援
Support towards CCS Demonstration Project by GCCSI
Session 4A(i)低品位炭技術(i)Low Rank Coal Utilization Technologies (i)Session 4A(ii) 低品位炭技術(ii)
Low Rank Coal Utilization Technologies (ii)
Session 4B(i) APEC エコノミーにおける CCS 開発動向(i)CCS Development in APEC Economies(i)Session 4B(ii) APEC エコノミーにおける CCS 開発動向(ii)
CCS Development in APEC Economies(ii)Session 5
パネルディスカッション；APEC 域における CO2 削減の方向性
Panel Discussion; Direction on CO2 Reduction in APEC Region
Closing Remarks 閉会の辞
三日目(10 月 29 日)
Technical Tour EAGLE Pilot Plant (電源開発㈱若松研究所)見学(3) 概要 開会セッション
 司会
NEDO 和坂理事（開会セッション議長）は、冒頭にて、今後 APEC、特にアジア地域においては経済発展により石炭需要が増えることが予想されるため、我が国の高効率且つクリ

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ーンな CCT の導入普及及び CCS 技術の開発普及をしていかなければならないと挨拶された。
APEC EGCFE議長による開会挨拶
スマウス議長は、APEC を代表して、気候変動への影響を削減することが必要であり、本セミナーにおける CCT と CCS は的を得た課題である、2050 年までに 50％削減しなければならないが、その半分は途上国で削減する必要があり、APEC エコ
ノミーにおける削減の重要性を認識しなければならない、APEC における石炭火力の高効率化と CCS の実現は CO2 削減にとって極めて重要であり、このセミナーが果たす役割は大きいと開会挨拶をした。
麻生福岡県知事による来賓挨拶①
麻生知事は、人口 500 万人、自動車をはじめとする各種産業が発展している福岡県にようこそと挨拶された。50 年前は炭鉱で栄えていたが、石油によって突然消えた。しかし、九州大学では炭鉱技術、石炭利用技術を教えているし、九州大学と県で水素プロジェクトを進めており、これにより環境問題を解決していきたい。石炭は水素製造に重要であり、この
石炭セミナーは意義深い。福岡県の福は幸せ、岡はその真ん中にいることを意味しており、皆様の滞在が幸せでありますよう、またセミナーの成功を祈ると挨拶された。
METI安藤資源・燃料部長による来賓挨拶②
参加エコノミーに対する歓迎の挨拶と事務方に対するねぎらいに続き、APEC は世界のGDP の半分を占めており、CO2 が大きな問題になっているので、APEC のエネルギー問
題は極めて重要である。エネルギー基本計画にも、石炭の安定供給と石炭火力の低炭素化を実現するとしており、また、APEC エネルギー大臣会合においても先端的石炭火力の導入のイニシアティブをとるよう指示されたところであると挨拶された。
特別講演①METI安藤資源・燃料部長
世界の一次エネルギーの四分の一が石炭、石炭火力は今後も増大し、現在の 40％から2030 年には 44％になる。石炭政策の基本は、低炭素化と安定供給である。低炭素化は
日本及び世界の石炭火力の高効率化が第一である。IGCC 及び IGFC により効率 65％を目指している。ゼロエミッション化のために CCS の開発も行っている。大崎クールジェンは
IGCC+CCS、30 万ｋW 以上の新設は、CCS Ready を検討している。
カライドの酸素燃焼プロジェクト、ゼロジェンプロジェクトを豪州と一緒に実施している。世界全体の石炭火力市場の 70％がアジアにあり、原子力の 10 倍の市場である。現在、2 国間
CO2 オフセットメカニズムを検討している。日本の CCT に一層磨きをかけて、世界の産炭
国と Win-Win の関係を構築していきたいと述べられた。
特別講演②IEAデスファルシー局長(エネルギー政策技術局長)
ヨーロッパで一般の人に話を聞くと石炭は古く、姿を消すといわれるが、一時エネルギーの四分の一、電力の 40％を占め、今後も重要な役割を果たしていく。石炭消費は 2000
年から増加しており、エネルギーとして顕在化している。世界中にあり、貿易も 15％を占めている。電力で最も大きなエネルギーである。中国の石炭生産は、2030 年までに 40 億トンになる。ブルーマップシナリオでは、2050 年までに CO2 排出量を半減、削減量の 3 分の 2 は非 OECD で実施が必要、電力部門が大きな役割を担う必要がある。ブルーマップ
シナリオでは、削減量の 2 分の 1 は再生可能エネルギー、4 分の 1 を原子力、さらに 4 分の 1 を CCS で解決できるとしている。
高効率、高環境対応の磯子火力の技術を世界に広めることが重要、CCS は必要な削減の 20％で、2050 年に 3000 か所以上が必要となり、特に中国、インドで必要。また、石炭火力のみならず、鉄鋼やその他の産業でも必要となる。
特別講演③米国DOEダニエルス室長
米国において、CCS は気候変動対策のポートフォリオとして使われている。米国 DOE における CCS プログラムの予算は、合計 3.4 ビリオンドルで、FutureGen
1,000M ドル
CCPI
800M ドル
Industrial
885M ドル
パオロット規模 CCS
635M ドル5

地下調査
50M ドル
CCS 教育・トレーニング
20M ドルCCS は米国でどのくらい必要かを計算したところ、350GW のうち 100GW、およそ 3 分の1 に必要であることが分かった。また、現在の法律の下で実施しているが、特別な法律を 2年間で作る予定である。炭素価格がないのが障壁となっている。新しいツールを使って普及を図っていかなければならない、信頼性をどのようにして得るか、安全な貯留ができるか、
等課題は多い。
 スペシャルレポート APECにおける石炭需給－エネ研・豪州、インドネシア、南アフリカ、ロシアが輸出国、インドネシア、ロシアの輸出量が増えている。
・中国の輸入量が 9000 万トン以上増加、2010 年は 1.6 億トン程度輸入するだろう。
・APEC の石炭生産、消費は、全体の 70～75％、石炭による発電は 60％を占める。
・APEC 地域の石炭需要は、2035 年に 85 億トンと予測。世界の石炭消費の 65％を占める。発電による CO2 が 30％。
 セッション1A・BのAPECエコノミーの各地域の石炭需給については、6カ国（カナダ、豪
州、インドネシア、タイ、韓国、フィリピン）から発表を得た。
 途中、特別講演が3本、基調講演が1本発表された。
 特別講演 九大永島副学長によるアジアでのクリーンなエネルギー
 特別講演 ADBキム研究主幹によるADBにおける高効率石炭火力発電への支援
 特別講演 GCCSIボナー上級専門家におけるGCCSIによるCCS実証試験に対する支援 基調講演 JCOAL中垣会長によるAPEC域における環境問題を解決するための日本の役割
 セッション2・3の 高効率発電技術については、中国・韓国・日本から其々USC技術についての発表を、IGCC等については日本と米国から其々発表があったが、その中でも、中国のUSC導入が急速に進んでおり、以下のような状況であることを報告する。
・2000 年以来 USC の開発を進めている。
・ボイラ、タービン、排ガス浄化設備、運転技術等を基に、1000MW と 600MW について、25-28MPa、600℃の開発をしてきた。
・2006 年から 1000MW、2007 年から 600MW の運転が始まった。
・2009 年までに 1000MW が 19 基運転されており、68 基が建設中である。600MW
は 20 基が運転中で、50 基が建設中である。
・Yuhuan 発電所には４基の 1000MW があり、2006 年から 2007 年に運転試験が行われ、設計通りの性能が得られた。
・Kanshan 発電所は 600MW が 2 基で、2008 年 7 月に完成し、運転されている。
・今後 10 年で中国の USC 設備は 500GW をこえ、全体の 50 %になるであろう。
・2003 年の石炭消費量は、380ｇ/kWh であったが、2009 年は 342ｇ/kWh となった。
・700℃のボイラ、タービンの開発も国家が決定した。
 セッション 4A 低品位炭技術については、6 本（含、日本からの発表 5 本）発表が行われた。
 セッション 4B APEC 各国地域における CCS 開発動向については、7 本（含、日本からの発表 2 本）発表が行われた。
 セッション5 パネルディスカッション
モデレーターの一橋大学橘川教授が、「CO2 排出を 2050 年までに半減するには、アジア地域で減らすことが必要であり、ターゲットを満たすには CCS が必要。いつまでにどれだけ必要かが問題である。CCS をうまく使わないとコストは 3 倍にも 4 倍にもなる」として、各パネリストに APEC 地域で CO2 を減らすにはどうしたらいいかで意見を求めた。5 名のパネリ
ストからは、「参加しているエコノミーが協力する必要がある。技術と理解を移転していく必要がある。知識を共有する必要がある。CCS トレーニングのワークショップをやることが必要、
公共教育、エンジニアリング情報の共有が必要、このグループの中でスピードを上げるための交渉が必要、途上国でも準備が必要、APEC 諸国がロードマップを作ることが必要、

6

ロッテルダムでは法規制の枠組み等で失敗したが一般大衆の認知が必要、2 国間オフセットの導入や CCS を産炭国で処理することも必要、CO2 の再利用の方法(CO2 に付加価値をつける)を開発することが必要」等の意見が出された。
インドネシアからは、数年前はどうして途上国が CO2 を削減しなければいけないのかと思ったが、今は途上国も削減しないと大変なことになると考えているとの発言があり、非常に良かった。途上国も一緒になって考えなければいけないというプラットフォームができつつあるかと感じた。
最後に、橘川教授は、高効率化を促進するためには Win-Win の仕組みが必要、CCS
は経済性を上げること、IGCC との組み合わせで価値を高めることが必要であると結ばれた。
 閉会の辞スマウス議長は、最後の閉会の辞にて、「情報を普及することが必要であり、今回のセミナー
は、CCT と CO2 削減、CCS の重要性の情報が発信できたと思う。石炭はなくならない、長期的にも必要。石炭はきちんと使えば環境への影響は小さいことを示すことが重要。CO2 を削減すれば、石炭を使っていくことができる。風力やバイオマスにも反対する人はいる。どのよ
うにエネルギーを使うかについては、対話が必要。政策決定者だけで決めることではない。
開かれたコミュニケーションが必要。クリーンなエネルギーを使って経済発展することが重要。
よりクリエイティブなアイデアを出してほしい」と述べた。

(4) 統括及び所感 APEC首脳会議の2週間前の開催ということで、APECの名の下に開催される本セミナーへの妨害行為対策や10月28日の竹島の日（会場であるヒルトン福岡シーホークから200m先に韓国領事館があり、そこへの左派・右派による街宣車等による抗議デモ）への対策があり、警備に非常に神経を使わなければいけない面があったが、結果的には無事に終了できた。
 米議長が閉会の辞でも述べたように、例年であれば2日目は参加者数が半分位に減ることが多かったが、今回の福岡でのセミナーでは、2日目もかなりの参加者が残り、非常に充実した会議となった。2日目のテーマが、低品位炭、CCS及びパネルディスカッションということもあり、テーマ設定が時節柄適切であったと思われる。
 国際会議の成果が問われる中で、本セミナーもいつも会議の成果が問われるが、やったか
らどうこうという結果が出るものではないが、パネルディスカッションのテーマでもあった「APEC域でCO2排出削減をどのように実行していくか」については、各国任せではなく、我が国がリーダーシップを取り、各国と対話し、またAPEC全体を纏め上げて、世界に示していくことが重要と思われる。事務局として、各国とのチャネルを使って、この実現に向けて実務を実施し、政府をサポートしていくべきと思われる。GCCSIやIEA-GHGとも協力すれば、我が国からの押し付けにならずに、APECを纏めていくことができると思われる。
 APEC が拠出している調査予算で、APEC 地域で CCS の実現またはそれを促進する
方法を見出す調査を実施するのもいいかも知れない。

セミナー吊看板

受付の様子

7

APEC EGCFE 議長による開会挨拶

セミナーの様子

講演者関係者一同 photo session

麻生福岡県知事挨拶

中垣会長基調講演

滝本九州経済局長歓迎会挨拶

見学会の様子（電発若松研究所）
州経済 長歓迎会挨拶

見学会での記念撮影

セミナー講演者記念撮影
8

２． 講演概要

9

2. 講演概要
1) 開会セッション Opening Session
セッション議長（日本）
独立行政法人新エネルギー・産業技術総合開発機構
理事 和坂 貞夫氏
Session Chair (Japan)
Mr. Sadao Wasaka
Executive Director,
New Energy and Industrial Technology Development
Organization (NEDO)(1) 開会挨拶 Opening Address
APEC 化石燃料専門家委会合グループ議長
スコット・スマウス氏
Mr. Scott Smouse
Chair,APEC EGCFE Chair

APEC・EGCFE の議長をしている S．Smouse である。開催を支援頂いた各機関に感謝する。
幅広い関係者が知見を共有するため、CO2 排出削減にむけたクリーン石炭技術 CCT の展開について国際セミナーを開催する。セミナーのテーマは「クリーンコール技術の新たな展開と CO2 排出削減」である。
今年はメキシコのカンクン（Cancun）において気候変動枠組条約締約国会議COP16も開催が予定されている。
気候変動に対応して低炭素社会への移行が必要になっている一方、地球温暖化効果ガス GHG 排出削減コストの経済への影響も懸念される。APEC エコノミーにおいて CCT 展開と CCS は重要課題である。
地球温暖化を増進させないためには、温度上昇を 2℃以内に抑制することが必要であり、そのために 2050 年の GHG 排出 50%削減が必要になる。EWG（エネルギー作業部会；本専門家会合グループの上部機関）は削減技術の多様なオプションを示している。IEA では 2020 年には 20 の CCS プロジェ
クトが必要と検討している。国際的枠組みでは、CCS イニシアティブ等が設立され CCS に対する課題
解決に取り組んでいる。
IEA-WEO2009によれば、APEC地域は世界のエネルギー需要の60%を占め、エネルギー輸入地域
であるが、経済成長に伴い需要は拡大している。世界のエネルギー需要は 2007 年から 2030 年に 40%増加すると予測されている。このことは APEC 域において、エネルギー協力が重要課題となっていることを意味する。

10

石炭は多くの課題に直面している。石炭は、世界の至る地域で生産消費されて、経済安定に寄与しているにも拘わらず、攻撃の対象となっている。IEA の調査によれば、中国、インドを中心に電力分野
において石炭からの CO2 排出は急増する。
既存火力の代替、高効率化が早急に必要である。Capture-Ready 石炭火力発電所の重要性は大きい。
CCT と CCS に関連する最新の EGCFE（本化石燃料専門家委会合グリープ）の活動を広く公開していくつもりである。そして地域において関連する IEA イベントとも協調していく予定をしている。
多くの政府と産業界の指導者は CCS 導入により石炭利用方法が大きく変化すべきことに同意した。
しかし、CCS 導入には経済的、技術的、法規制、一般受容性など多くの課題が存在する。石炭がグローバルなエネルギー構成において重要な役割を演じていくなら、これらの挑戦課題は克服されるであろう。
今日と明日 2 日間のセミナーにおいて、専門家間において課題克服のための協議できることを期待する。

(2) 来賓挨拶 1 Welcome Remarks 1
経済産業省資源エネルギー庁
資源・燃料部長
安藤 久佳氏
Mr. Hisayoshi Ando
Director-General,
Natural Resources and Fuel Department,
Agency for Natural Resources and Energy (ANRE),
Ministry of Economy, Trade and Industry (METI)
参加エコノミーに対する歓迎の挨拶と事務方に対するねぎらいに続き、APECは世界のGDPの半分を占めており、CO2が大きな問題になっているので、APECのエネルギー問題は極めて重要である。エネ
ルギー基本計画にも、石炭の安定供給と石炭火力の低炭素化を実現するとしており、また、APECエネ
ルギー大臣会合においても先端的石炭火力の導入のイニシアティブをとるよう指示されたところであると挨拶された。

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(3) 来賓挨拶 2 Welcome Remarks 2
福岡県知事
麻生 渡氏
Mr. Wataru Aso
Governor
Fukuoka Prefecture

心から参加者の皆さんを歓迎する。
福岡県は人口500万人、自動車、鉄鋼、化学、電気・電子工業が盛んである。50年前は炭鉱業が盛んであったが、石油の台頭で炭鉱は消えた。しかしながら、石炭技術は維持されている。一例が九州大学、同大学の持田教授がこの会議もリードしている。
福岡県では、EAGLE パイロットプラント、等の技術開発も盛んに行われている。石炭のガス化と水素製造は福岡県と関係が深い。
他に県が力を入れているのは、水素プロジェクトであり、『水素エネルギー戦略会議』を先日主催した。
福岡での皆さんの滞在が幸せなものとなることと、このセミナーの成功をお祈りする。

(4) 特別講演 1 Featured Speech 1
エネルギー基本計画における石炭の位置付
The Position of Coal on the New Strategic Energy Plan
経済産業省資源エネルギー庁
資源・燃料部長
安藤 久佳氏
Mr. Hisayoshi Ando
Director-General,
Natural Resources and Fuel Department,
Agency for Natural Resources and Energy (ANRE),
Ministry of Economy, Trade and Industry (METI)
1. 世界のエネルギー資源に占める石炭の役割(1) 世界の一次エネルギー消費で石炭は 27%を占め 2030 年には 29%に年率 1.5%増加し、消費量は 1.5 倍の見通し。世界の石炭火力発電割合は 42%、2030 年には 44%、発電量は倍増の見通し。
2. エネルギー基本計画における石炭の位置付(1) 石炭火力の低炭素化に向けて、国内石炭火力の更なる低炭素化と海外石炭火力の低炭素化を推進(2) 石炭資源の安定供給確保のため、産炭国協力の推進と低品位炭の有効活用
3. 石炭火力発電の低炭素化

12(1) 我が国の石炭火力の熱効率は 42%と世界最高水準にある。また、国内（高砂）発電所の例でいえば、40 年後も新設当時の熱効率を維持し、運転管理にもノウハウを保有している。
(2) 国内石炭火力の更なる低炭素化とゼロエミッション化への推進のため、IGCC で 57%、更にIGCC と燃料電池と組み合わせた IGFC 目標は 65%、高効率化の技術開発を進めている。
(3) 国内では大崎 CoolGen 計画 170MW-IGCC と CO2 分離回収の大型実証を実施する。国際
展開は、豪州において酸素燃焼と CCS を組み合わせた Callide-A（総額 180 億円）共同研究、
ZeroGen 計画（総額 3,400 億円）を実施(4) 石炭火力は 2007～2030 年に設備容量で倍増、新設市場規模は 200～400 兆円と原子力市場の 10 倍。アジアが 7 割を占め、特に中国（502→1275GW）、インド（78→364GW）における需要増加が顕著。石炭依存の経済（中国・米国・インド）において既存石炭火力を日本の高効率火力に代替すると日本の年間 CO2 排出量に相当する削減が可能との試算もある。
(5) 二国間オフセットメカニズムによる日本の技術貢献について。現状の CDM は手続きの煩雑化などプロジェクト承認まで時間がかかって多くの制約がある。日本経済の関心事項として、
インフラ・システム輸出が成長戦略にあり。相手経済における産業構造、電源開発政策、官民の役割などの多様性に対応した技術移転を重要視している。二国間で排出削減を承認しwin-win の関係になるメカニズムを提唱している。
4. 人材確保と育成の重要性も認識している。まとめると、日本の CCT に一層磨きをかけて、フルに活用することにより産炭国経済との win-win 関係構築に取り組む。それが、エネルギー政策や地球環境問題への対応にとって、また、新しい産業分野開拓・拡大という視点からも重要である。

(5) 特別講演 2 Featured Speech 2
将来の低炭素化社会における石炭の役割
The Role of Coal in a Low-Carbon Future
IEA（国際エネルギー機関）
持続的エネルギー政策・技術局長
ボー・ディスファルシー氏
Mr. Bo Diczfalusy
Director,
Directorate of Sustainable Energy Policy andTechnology,
International Energy Agency (IEA)
ヨーロッパで一般の人に話を聞くと、石炭は古く、姿を消すといわれるが、一次エネルギーの四分の一、電力の40％を占め、今後も重要な役割を果たしていく。石炭消費は2000年から増加しており、エネルギーとして顕在化している。世界中にあり、貿易も15％を占めている。電力で最も大きなエネルギーである。中国の石炭生産は、2030年までに40億トンになる。
ブルーマップシナリオでは、2050年までにCO2排出量を半減、削減量の3分の2は非OECDで実施が必要、電力部門が大きな役割を担う必要がある。ブルーマップシナリオでは、削減量の2分の1は再生可能エネルギー、4分の1を原子力、さらに4分の1をCCSで解決できるとしている。
高効率、高環境対応の磯子火力の技術を世界に広めることが重要、CCSは必要な削減の20％で、2050年に3000か所以上が必要となり、特に中国、インドで必要。
また、石炭火力のみならず、鉄鋼やその他の産業でも必要となる。

13

(6) 特別講演 3 Featured Speech 3
CCS 開発動向CCS Deveopment Status
米国エネルギー省
化石燃料庁 企画・環境分析室長
ジャラド・ダニエルズ氏
Mr. Jarad Daniels
Director,
Office of Planning & Environmental Analysis,,
Office of Fossil Energy,
Department of Energy (US)・CCS プログラムの米国における進捗状況
・CCS は気候変動対策のポートフォリオの一つ・ＩＥＡのロードマップと同様に、2100 年までに CCS は大きな部分を占める・CCS に対する政府の支援
・昨年 34 億 USD を経済刺激策を兼ねて支出（FuturGen2.0：10 億 USD、Clean Coal Initiative：8 億 USD 等）
・CCS デモプロジェクトは Utility（3 件）から産業の分野で合計 10 件が進行中（ノースダコタ：120MW－100MtCO2 回収、NRG：60MW－PCF 冷却アンモニア法回収、
ルイジアナ：420 万 t/CO2 レクチゾール法による回収、等）・FutureGen2.0：（IGCC は既にあるので）酸素燃焼に重心を置く→202MWe の既設プラントで試験・CCS の R&D 予算は、2010 年：404MUSD、2011 年要求：403.85MUSD
・米国には十分な貯留ポテンシャルあり、2011～2015 に 9 か所で親水性、安全性の大容量テストを行う
・シミュレーション（モデリング）により CCS(回収法)の設計サイクルの短縮を図り、ベンチスケールからパイロットのスピードアップを図る
・CCS には技術／非技術の両面の課題がある。8 月に 100 人の学者・専門家が集められ Task
Fource が作られた
・CCS には複雑な法律が関わっているので、環境庁が CCS のための新法を準備している・Carbon 価格が形成されていないことが課題
・CCS の普及には法や費用対効果が大きく影響する・CCS は重要であり、これを進めなければならない

14

(7) 特別レポート Special Report
APEC 域における CO2 削減に向けた石炭需給動向及び対策の見通し
Outlook of Coal Demand/Supply and Countermeasures towards CO2 Reduction in the APEC Region
財団法人日本エネルギー経済研究所
戦略・産業ユニット石炭グループ 研究主幹
佐川 篤男氏Mr. Atsuo Sagawa
Senior Analyst,
Coal Group,
Strategy and Industrial Research Unit,
The Institute of Energy Economics, Japan (IEEJ)

1)2)

石炭需給の現状
世界の一次エネルギー消費で石炭は 27%を占め 2030 年には 29%に年率1.5%増加し、消費量は 1.5倍の見通し。世界の石炭火力発電割合は 42%、2030 年には 44%、発電量は倍増の見通し。
3) 石炭需給見通し
4) 石炭火力の低炭素化に向けて、国内石炭火力の更なる低炭素化と海外石炭火力の低炭素化を推進5) 石炭資源の安定供給確保のため、産炭国協力の推進と低品位炭の有効活用
6) 石炭火力発電の低炭素化
7) 我が国の石炭火力の熱効率は 42%と世界最高水準にある。また、国内（高砂）発電所の例でいえば、40 年後も新設当時の熱効率を維持し、運転管理にもノウハウを保有している。
8) 国内石炭火力の更なる低炭素化とゼロエミッション化への推進のため、IGCC で 57%、更に IGCC と燃料電池と組み合わせた IGFC 目標は 65%、高効率化の技術開発を進めている。
9) 国内では大崎 CoolGen 計画 170MW-IGCC と CO2 分離回収の大型実証を実施する。国際展開は、
豪州において酸素燃焼と CCS を組み合わせた Callide-A（総額180億円）共同研究、ZeroGen 計画（総額 3,400 億円）を実施
10) 石炭火力は 2007～2030 年に設備容量で倍増、新設市場規模は 200～400 兆円と原子力市場の 10倍。アジアが 7 割を占め、特に中国（502→1275GW）、インド（78→364GW）における需要増加が顕著。石炭依存の経済（中国・米国・インド）において既存石炭火力を日本の高効率火力に代替すると日本の年間 CO2 排出量に相当する削減が可能との試算もある。
11) 二国間オフセットメカニズムによる日本の技術貢献について。現状の CDM は手続きの煩雑化など
プロジェクト承認まで時間がかかって多くの制約がある。日本経済の関心事項として、インフラ・シ
ステム輸出が成長戦略にあり。相手経済における産業構造、電源開発政策、官民の役割などの多様性に対応した技術移転を重要視している。二国間で排出削減を承認し win-win の関係になるメカ
ニズムを提唱している。
12) 人材確保と育成の重要性も認識している。まとめると、日本の CCT に一層磨きをかけて、フルに活用することにより産炭国経済との win-win 関係構築に取り組む。それが、エネルギー政策や地球環境問題への対応にとって、また、新しい産業分野開拓・拡大という視点からも重要。

152) セッション 1A APEC エコノミーにおける石炭政策 (i)Session 1A
Coal Policy in the APEC Economies (i)セッション議長（韓国）韓国エネルギー研究院(KIER)
研究主幹
ジホ・ヨー博士
Session Chair (Korea)
Dr. Jiho Yoo
Senior Research Engineer,
Korea Institute of Energy Research(KIER)(1) 講演 1 カナダにおける石炭需給動向
Speech 1 Coal Demand & Supply in Canada
カナダ天然資源総局
上級化学技術顧問
フランク・モーリツ博士
Dr. Frank Mourits
Senior Science & Technology Advisor,
Natural Resources Canada (NRCaN)

１．カナダの石炭概要(1) 石炭セクター
生産量は7千万トン（原料炭40%、一般炭60%）、22の炭鉱、19の石炭火力、5000人の労働力。
その他関連産業としては鉄道港湾などの輸送関係、装置、探査など。
(2) 石炭の役割
石炭は一次エネルギーの約 9%、発電量の 15%。年間 6 千万トン消費、内 90%が発電。1/3 は輸入している。主な産炭地が西部のため、内陸輸送のコストから、東部地区は米国から輸入、西部は輸出に回している。
(3) 資源
可採埋蔵量は 120 億トン(4) 消費・生産・輸出入、需要予測
石炭消費は一定、最近微減、その理由はオンタリオ州で石炭火力発電所が古いものから閉鎖されているため。2014 年までに州内石炭火力発電全廃が決まっている。需要は 2014 年以降4千万トンで一定になる模様。
(5) 政策資源は州政府所有で連邦政府は権限なし。連邦政府では、クリーンコール技術開発、環境問
題、健康問題、種族問題、対外問題などを扱う。基本的な考え方としてカナダは将来的にも石炭輸出国としての競争力は維持する。

16

2. 質疑応答Q) オンタリオ州の石炭火力全廃は電力料金の高騰など住民の反対はなかったのか？
A) 基本は環境規制の問題で全廃を先に決めたという事であるが、まさにその点がいま盛んに議論されている。本件含めエネルギー政策は現政権の重要な問題となっている。

(2) 講演 2 フィリピンにおける石炭政策と CO2 削減
Speech 2 Coal Policy and CO2 Reduction in the Philippines
フィリピン国エネルギー省
エネルギー資源開発管理局長
アリシア・レイヤス氏
Ms. Alicia N. Reyes
Director,
Energy Resources Development and Management(ERDB),
Department of Energy, the Philippines

1. 制度（1） フィリピン政府は Coal Development Act 1976 を制定、探査・開発・採掘・利用を促進。資源は政府所有、鉱業権者は契約により期間を定めて政府と契約。利益の 30％は政府納入。 Philippine
Energy Contracting Round と呼ばれ、2009 年で 16 件存在。
2. 石炭産業の現状（1） 2009 年の石炭生産は 517 万 6,212 トン、需要の 43％相当である。主要炭鉱は Semirara で、出炭量は 484 万 6,866 トン、約半分の 230 万トンはインド、中国、タイ、香港、台湾等に輸出されている。
（2） 石炭火力発電容量は 370 万 kW。2030 年までの電力需給見通しによれば、毎年 70 万kW の追加
的な容量拡大が必要。2012 年から 2014 年に 180 万 kW の石炭火力建設を予想。
（3） 石炭輸入は 702 万 6,718 トンで、その内 638 万トンはインドネシア炭。
（4） 国内消費は 1,206 万トン、1995 年の石炭火力運転開始以降で電力分野消費が急増しており 75％、セメント産業が 19％を占める。
（5） CCS ネットワーク構築、米国との共同、様々な国際枠組みへの参画。
3. クリーンコールイニシアティブ(1) Coal Development Act （1977）では事業者（国との契約者）は鉱害防止に努め操業条件に適合した経済的な操業を行う必要がある。環境アセスメントにも留意する。
(2) 石炭利用者は環境維持・公害防止に努め、対策を講じることが規定されている。化石燃料を固定排出源で利用する場合の硫黄は 1％超えてはならない
4. まとめ（1） 電力需要に対応するため、石炭火力は経済性と時間的な問題から最適な選択肢であるため、石炭火力の拡大が計画されている。
（2） 環境問題が優先課題となった現在、発電設備への CCT 適用が適当であり、フィリピンの比較的低品位の石炭利用においては坑口発電プロジェクトが適当である。
（3） GHG 排出削減基準は標準化されていないが、排出削減技術は導入されつつある。

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(3) 講演 3 韓国における石炭政策と CO2 削減
Speech 3 Coal Policy and CO2 Reduction in Korea
韓国エネルギー公社研究所(KEPCO RI)
プロジェクト・リーダー
サンチュル・キム博士
Dr. Sungchul Kim
Project Leader,
KEPCO Research Institute１．韓国の電力産業の現状
発電容量は 7250MW、その 37％は石炭、今後は石炭火力をつぶしてガス、原子力を増やす方向。国内で石炭生産はなく、豪州、インドネシアからの輸入で賄っている。石炭火力の効率改善
は 90 年代に進んだ。温室効果ガス削減に高い目標を設定。PostConbustion に関しては、2014 年に 10 万 KW クラスのパイロットプラントを計画している。
２．今後の政策CCS に関して、経済省が 2010～2020 年で 19.2 億ドル規模のプロジェクトを進行中。そのうち 10
億ドルが政府プロジェクト。その他石炭火力に関しては、輸入炭の多角化の一課として LRC のブ
レンドを検討中。
３．Q&A
Q) 石炭火力のリプレース計画はあるのか？
A) よりクリーンな政策を基本としているので、石炭火力の改造及びリプレースよりも、原子力に注力している。また IGCC は現在 10 プラントで計画進行中。

18

3) セッション 1B APEC エコノミーにおける石炭政策 (ii)
Session 1B
Coal Policy in the APEC Economies (ii)セッション議長（日本）
経済産業省資源エネルギー庁
資源・燃料部石炭課長
橋口 昌道氏
Session Chair (Japan)
Mr. Masamichi Hashiguchi
Director, Coal Division,
Natural Resources and Fuel
Department,
Agency for Natural Resources andEnergy (ANRE),
Ministry of Economy, Trade and Industry(METI)(1) 講演 1 豪州における石炭政策と CO2 削減
Speech 1 Coal Policy and CO2 Reduction in Australia
豪州連邦資源エネルギー観光省
低炭素石炭政策課長
ジョン・カラス氏
Mr. John KarasManager, Low Emission Coal Policy Section,
Department of Resources, Energy and Tourism(DRET), Australia

１．石炭状況
・石炭火力の 80％が石炭火力。今後も重要なエネルギーである。
・効率の改善が重要であるが、大幅に CO2 を減らすには CCS が必要である。
・国際的にエネルギー供給者としての責任がある。
２．CCS
・CCS 技術を早期に実用化して、世界に示していきたい。
・2020 年までに 2000 年比で 5％CO2 を減らしたい。国際協力をすれば 25％くらいまで可能である。
・豪州政府の CCS イニシアティブ
低エミッションコールイニシアティブ 400million ドル
CCS フラグシッププログラム 2billion ドル
Global CCS Institute 100 million/y など
・パイロットプロジェクトーOtway、PCC Pilots
・中規模実証プロジェクトーカライド酸素燃焼プロジェクト

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・大規模プロジェクトーCCS フラグシッププログラム
Wandoan: IGCC＋CCS
ZeroGen： IGCC＋CCS
Collie South West Hub
CarbonNet Hub
そのほか Gorgon LNG Project、HRL IDGCC、新日鉄エンジ ECOPRO・APEC は CCS における国際協力で重要な役割を担っている。

(2) 講演 2 インドネシアにおける石炭政策と CO2 削減
Speech 2 Coal Policy and CO2 Reduction in Indonesia
インドネシア国エネルギー・鉱物資源省
地熱石炭総局資源基準課長
トリ・ウィナルノ氏
Mr. Tri Winarno
Head of Mineral Standarization,
Directorate of Mineral and Coal,
Ministry of Energy and Mineral Resources (MEMR)
Indonesia

1.

石炭の現状
・埋蔵量が豊富にある・生産量は 2004 年の 2 倍になった。2009 年の生産量は 256 百万トン。
・75％が輸出であるが、今後は国内消費も増える。
・スマトラ、カリマンタンに多く埋蔵されている。
・国家のエネルギー開発戦略は、今後石油、天然ガスは減らして石炭を増やす計画である。
・政府が石炭のリファレンス価格を決めている。
2.
CO2 の削減
・2020 年までに 26％削減する。国際的支援があれば、41％減らせる。
・CO2 排出の 80％は森林破壊によるものである。
・石炭火力には、SC や IGCC を導入していく予定である。

20

(3) 講演 3 タイ石炭政策と CO2 削減
Speech3 Coal Policy and CO2 Reduction in Thailand
タイ国モングル技術大学トンブリ校
講師 (元エネルギー省上級管理職)
ブーンロッド・サジャクルナキット博士
Dr. Boonrod Sajjakulnukit
Lectuturar,
Monglut’s University of Technology, Thonburi, Thailand(former Senior Officials, Ministry of Energy)

1. タイのエネルギー事情（4） タイは人口 6400 万人を有し、2009 年で総輸入額の 58％に相当する約 500（470）億ドルを輸入した。
① 一次エネルギー構成は天然ガス40％、石油35％、石炭は11％。分野では産業用38％、輸送 35％。
（5） 石炭事情① 2009 年の石炭需要は 3420 万トン、産業用 1270 万トン、電力 2150 万トン。今後、2030 年に 4870 万トン、うち産業用 1520 万トン、電力 3350 万トンに増加見込み。
② 2009 年末の燃料別発電量は 145,233GWh、2010 年 1-3 月は 38,321.6GWh③ 2006 年の IPP 設立以降に石炭需要が増加、電源開発計画では天然ガス依存を70％から39％に削減する。
④ 電力計画において 2010 年は電力公社、IPP に加えて海外から買電する。2014 年以降老朽設備を廃棄。
⑤ 発電燃料別の構成は、2010 年の褐炭 11％、石炭 8％、2030 年には 2％と 21％
2. 石炭政策と CO2 削減（1） 石炭はタイ経済のエネルギーセキュリティにとり重要であるが、将来の石炭利用は環境面での課題がある。
（2） CCT でのオプションは、SC で IGCC+CCS に関しては情報収集段階。循環流動床によるコジェネレーション、産業用として CWM、石炭ガス化（3） 2030 年で 2005 年比 25％の省エネで最終エネルギー消費 3340 万トン（toe）を削減
3. まとめ（1） 石炭はエネルギーセキュリティ上で重要な選択肢（2） 将来の石炭利用は増加するが、より効率的となり CO2 排出は削減（3） 国家削減計画は 2011 年に公表される。

21

4) 特別講演 4 アジアにおけるクリーンなエネルギー
Features Speech 4 Clean Energy in Asia
九州大学
副学長
永島 英夫氏Prof Dr Hideo Nagashima
Vice President,
Kyushu University

今アジアを含め世界中でエネルギー問題、環境問題が起こっている。ここ九州でも中国からの黄砂、
NOｘ、SOｘ等大きな問題となっている。九州北部地区は石炭産業が盛んだった事もあり伝統的に石炭を取り扱う技術を保有している。そこで九州大学ではこれらの問題を解決すべくいろいろな取組を行っているので、それらを紹介したい。
九大では 4+2+4 アクションプランという将来計画を設定し、その中で、炭素高度利用技術、交際協力といったプロジェクトが進行中である。炭素利用技術に関しては新規ゼロエミッションガス化技術の開発、国際協力に関してはインドネシアや豪州ビクトリア州との強度プロジェクトがある。エネルギーに関しては 2010 年１２月に新しく水素研究センターを開設する。また海外にも事務所を設置し、積極的な情報発信に心掛けている。

22

5) セッション 2 高効率石炭火力発電技術の普及による CO2 削減(i)Session 2 CO2 Reduction by Diffusion of High-Efficient Coal-Fired Power Generation (i)独立行政法人新エネルギー・産業
技術総合開発機構
環境部主幹
中塚 正毅氏
Mr. Masaki Nakatsuka
Director,
Environment Department,
New Energy and Industrial Technology
Development Organization (NEDO)(1) 基調講演 1 APEC 域における環境問題を解決するための日本の役割
Keynote Address 1 Japan’s Role for solving the Environmental Issues in APEC Region
財団法人石炭エネルギーセンター
会長
中垣 喜彦（電源開発株式会社 相談役）
Mr. Yoshihiko Nakagaki
Chairman,Japan Coal Energy Center (JCOAL)

1. 世界のエネルギー起源 CO2 排出の 30％は石炭火力起源で 87 億トン、石炭火力からの CO2 排出削減が鍵。
2. 発電効率向上による削減余地がある。日本は従来から蒸気条件向上と発電ユニット大型化の二つの方法で高効率化してきた。高効率石炭火力導入と既存石炭火力の高効率化により 2006 年は
LHV41.4％を達成。世界では 80％は SC 以外の低効率な石炭火力。IEA によれば、高効率発電導入により 13.5～17 億トンの削減が可能としている。
3. 磯子石炭火力（265MWx2→600MWx2）では、2009 年 7 月に 43％効率の 2 号機の運開により、更新が完了し 17％の排出削減を達成。
4. 新設火力の高効率化とともに、高効率を維持する運転管理も重要。石炭火力の寿命は 40 年ともい
われるが、高砂発電所の例では 38％効率を 40 年間維持している。このような例は少ない。
5. 地球環境問題には、時間軸を考えて対応する必要。2020 年まで短期的には USC と木質バイオ混
焼、2030 年までの中期的には商用化の時代として、IGCC、A-USC および CCS で対応。2050 年までの長期目標は IGFC。
6. CCS には公共的な関与が重要。CCS は完成されていない技術段階で実証中。酸素燃焼はEAGLE プロジェクト、大崎 170MW プラントで大型実証し CaptureReady へのステップ

23

7. CCT 開発は技術輸出が動機である。石炭火力高効率化と CCS によりエネルギ安全保障と地球環境問題に対応(2) 講演 1 中国における USC 技術の導入と課題
Speech 1 Introduction and the Issues of USC Technology in China
中国電力投資集団公司
副社長
張 暁魯氏
（代読 海外事業部長 劉 占）
Ms. Xiaolu Zhang
Vice President,
China Power Investment Corporation(Mr. Lie Zhan, Director General of
Department of Overseas Business)
Note: Mr. Zhan read for Ms.Zhang

1.

中国における USC の開発と適用
・ 2000 年以来 USC の開発を進めている。
・ ボイラ、タービン、排ガス浄化設備、運転技術等を基に、1000MW と 600MW について、
25-28MPa、600℃の開発をしてきた。
・ 2006 年から 1000MW、2007 年から 600MW の運転が始まった。
・ 2009 年までに 1000MW が 19 基運転されており、68 基が建設中である。600MW は 20 基が運転中で、50 基が建設中である。

2.

中国における USC ユニットの技術的特徴
・ Yuhuan 発電所には４基の 1000MW があり、2006 年から 2007 年に運転試験が行われ、設計通りの性能が得られた。
・ Kanshan 発電所は 600MW が 2 基で、2008 年 7 月に完成し、運転されている。

3.

中国における USC 技術開発の動向
・ 今後 10 年で中国の USC 設備は 500GW をこえ、全体の 50 %になるであろう。
・ 2003 年の石炭消費量は、380ｇ/ｋWh であったが、2009 年は 342ｇ/ｋWh となった。
・ 700℃のボイラ、タービンの開発も国家が決定した。

24

(3) 講演 2 韓国における USC 技術の導入と課題
Speech 2 Introduction and the Issues of USC Technology in Korea
韓国南東電力会社
電力部長
セノマ・ロー氏
Dr. Seonma Loh
General Manager,
Power Department,
Korea South-East Power Company(KOSEP)

1. KOSEP 概要
・韓国南東電力社（KOSEP）は、KEPCO から 2001 年に分離独立した。
・合計約 9,000MW の設備容量を有す。
・従業員約 2,000 人
2. なぜ USC を使うか
・政府の政策である・燃料消費を減らすことができる→20％効率向上できる
・世界の環境ニーズに応える
3. CO2 削減
・800g/kWh 以下にするのは難しい。
・CCS が必要。
・USC で燃料が 13％減らせる。ただし、建設費の高さをカバーできるか？
4. まとめUSC 技術を低カロリー炭に使えるように、またコストを低くできるようにしていきたい。
その結果は、Yeonghung 5、6 号、Dangjin 9、10 号に反映させたい。

25

(4) 講演 3 日本における高効率石炭火力発電技術開発による CO2 削減
Speech 3 CO2 Reduction by Development of High-Efficient Coal-Fired Power Generation in Japan
九州電力株式会社
火力発電部門火力部長
伊﨑 数博氏
Mr. Kazuhiro Izaki
General Manager,
Thermal Power Department,
Thermal Power Generation Division,
Kyushu Electric Power Co., Ltd.

１．日本における戦後のエネルギー生産の変遷をみると石油依存から1970年代初めの石油危機を経て、多様化が図られてきた。現在は LNG、石炭のベストミックスが図られた状態で、今後も石炭火力の重要性は変わらない。日本では高効率化を推進しており、最先端の磯子発電所や、2017年予定の大崎クールジェン等技術革新が続いている。今後の技術としてはA－USC、LNG コンバ
インドサイクル、IGCC といった技術である。
今後のこれらの技術を石炭火力依存率の高い中国、インド等に展開することで低炭素化が図られるものと考える。特に 1KW 当たり１ｋｇ以上の石炭を使用している国は、USC の導入で 1 割 CO2削減を抑えることができる。
2．Q&A
Q1) 排出量削減の目標 800g/Kwh というのは USC でもかなり難しい課題ではないか？
A1 ) A-USC でもむずかしい。そこにいくのは CCS との組み合わせが必要。
Q2) 亜臨界→USC での 12%排出量削減は高い建設費を補えるのか？
A2) Yes
Q3) 技術導入後の効率維持はどうすれば良いか？
A3) メンテナンス手法の提供等手伝う仕組みができればと考えている。

26

6) 特別講演 5 効率的石炭火力発電に対する ADB の支援策
ADB’s Support towards Efficient Coal-Fired Power Generation
ADB（アジア開発銀行）
地域持続的開発部持続的インフラ部門
主幹部門長
ジョンイン・キム氏
Mr. Jong-Inn Kim
Lead Professional (Energy),
Sustainable Infrastructure Division,
Regional and Sustainable Development Department,
Asian Development Bank (ADB)
１． アジア太平洋域における石炭利用（1） ADB におけるアジア太平洋の定義は 48 ヶ国、APEC とは異なる。
（2） アジア太平洋域の石炭需要は 2030 年まで年率 2.1％で増加するが、全体エネルギー需要の伸び 2.4％より低い。石炭は 2006 年の 42％から 2030 年には 38％へ、増加分の 88％は電力分野。
（3） アジア太平洋域の電源構成は 2006 年の 58.1％から 2030 年には 52％。発電量は 6549TWh
から 14016TWh。
（4） 2006 年と 2030 年の各経済における石炭火力の割合は、中国 80.4→62.9％、インド 68.3→
63.9％、インドネシア 44.1→62.8％。
２． 石炭火力に対する ADB の関与（1）1972～1995 年：21 プロジェクト（24.89 憶 USD）
（2）1996～2002 年：0（3）2003～2009 年：7 プロジェクト（9.85 億 USD）
合計 28 プロジェクト 34.02 億 USD、公的 21 と民間 7 プロジェクト
３． ADB のエネルギー政策（1） エネルギー政策は、エネルギー効率向上と再生可能エネルギー促進、エネルギーへのすべて人々のアクセスおよびエネルギー分野の改革、人材育成並びに統制。
（2） ADB は石炭火力に対して、流動床、超臨界、超超臨界や脱硫技術の導入促進や普及策が織り込まれている場合、選択的な支援策をとっている。
４． 最近のプロジェクト（1） Visayas ベースロード電源開発プロジェクト（フィリピン）、200MW 発電に 2009 年 12 月承認（2） Tianjin IGCC、2010 年 2 月に 250MW 級 IGCC に 500 万 USD 融資（3） CCS では、CSLF、GCCSI など
５． まとめ（1） ADB は効率的な石炭火力発電プロジェクトに対し選択的な支援を行っている。
（2） 亜臨界石炭火力に融資する場合は、グリッド規模、開発水準などいくつかの考察項目がある。

27

7) セッション 3 高効率石炭火力発電技術の普及による CO2 削減(ii)Session 3 CO2 Reduction by Diffusion of High-Efficient Coal-Fired Power Generation (ii)
豪州連邦資源エネルギー観光省
低炭素石炭政策課長
ジョン・カラス氏
Mr. John KarasManager,
Low Emissions Coal Policy Section,
Department of Resources, Energy and Tourism(DRET)(1) 講演 1 IGCC と ICS －日本発世界へ －実証試験から商業ベースへの適用
Speech 1 IGCC and CCS – Advanced Technology from Japan to the World – From Demonstration toCommercial Application 三菱重工業株式会社
原動機事業本部技師長
IGCC･ガス化プロジェクト室長
橋本 貴雄氏
Mr. Takao Hashimoto
General Manager,
IGCC & Gasification Business
Power Systems HQ,
Mitsubishi Heavy Industries, Ltd. (MHI)

三菱重工は空気吹 IGCC の開発をしている。空気吹は、酸素を製造しなくてもよいので有利である。
・石炭はドライフィードで、空気吹きと合わせて、5％効率が高くできる。
・ガス化炉は、2 室 2 段で、メンブラン水冷壁構造である。
・IGCC＋CCS の検討をしており、ガス化ガスをシフト反応により、CO を水素に転換するが、水素リッチとなったガスがガスタービンで燃焼できるかについても検討した。
・豪州のゼロジェンプロジェクトに参加しており、現在 FS レポートを提出したところである。
・2016 年運転開始予定で、1700℃のガスタービンで、乾式クリーンアップを採用する予定である。

28

(2) 講演 2 米国におけるガス化プログラムの概要
Speech 2 Overview of US Gasification Program
米国エネルギー省
国立エネルギー技術研究所
国際関係グループリーダー
スコット・スマウス氏
Mr. Scott Smouse
International Team Leader,
US Department of Energy (US DOE)
National Energy Technology Laboratory(NETL)

米国のガス化計画を紹介する。
米国エネルギー省の根本的考えは、チュウ長官が発している「石炭資源は全世界に豊富にあるが、我々は石炭をよりクリーンに使うような道を早急に探さなくてはならない」との言葉に示されている
ように、石炭を効率的に使うために、且つ、より高い環境基準を保つためにも、発電所が増設されても電力のコストを下げることができるよう努めなければならない。
そのためには、
1) ガス化研究開発分野の焦点化
2) ITM 酸素技術の開発
3) 高圧力のソリッドポンプの開発
4) 高温合成ガスのスケールアップ技術の開発
5) IGCC 発電所のための水素輸送膜の開発
等の開発が必要である。
また、実際の運転性能を高めるためには、ヴァージニア研究所や、ガス技術研究所、NETL の中の調査開発室が様々な開発を行っている。
自分が所属している NETL の中の一機関である調査開発室のガス化プロジェクトを紹介する。
尚、開発した研究に関しては、システム分析室が、それらのシステムを分析・解説している。
先進的な技術である IGCC を使った結果、CCS のコストが下がった例を紹介する。
詳細は、NETL のガス化プログラムに関して web site を見て頂きたい。
www.netl.doe.gov/technologies/coalpower/gasification/index.html

298) 特別講演 6 GCCSI による CCS 実証試験プロジェクトに向けての支援
Featured Speech 6 Support towards CCS Demonstration Project by GCCSI
GCCSI
政策戦略局
研究主幹
マーク・ボナー氏
Mr. Mark Bonner
Senior Specialist,
Policy and Strategy,
Global CCS Institute (GCCSI)

地球温暖化対策としての CO2 削減シナリオ達成のためには、2050 年までに追加で 4 億 5 千万ポ
ンドが必要。これら対策を競合する３E（Energy, Enviornment, Econony）の観点で具体的提言として技術、情報、専門的なサービス、政策へのアドバイスを提案出来る組織として GCCSI が誕生した。これは 21 の国及び多くの民間団体がメンバーとなっている。CO2 削減の有効な手段は CCS だが、これには炭素価格の決定が伴わなければならないと考える。
現在 9 件の具体的プロジェクトが進行中だが、2020 年までにさらに 100 件、2050 年までには 3400
件（主に発展途上国）が必要。途上国のエネルギー問題を解決しつつさらに CCS が進むためには、
ADB、WB のサポートが必要で、GCCSI ではそのための技術、情報、専門的なサービス、政策へのアドバイス、戦略等、260 人の専門家スタッフが活動している。

30

9)

セッション 4A(i) 低品位炭技術 (i)Session 4A(i)Low Rank Coal Utilization Technology (i)セッション議長
九州大学
特任教授
持田 勲氏
Session Chair
Prof Dr Izao Mochida
Kyushu University(1) 講演 1 低品位炭の有効利用の調査と開発の導入
Speech 1 Introduction to Research and Development on the Efficient Utilization of Low Rank Coal
九州大学
特任教授
持田 勲氏
Prof Dr Izao Mochida
Kyushu University

Low Grade Coal の定義と今後の利用必要性について説明。
褐炭＝低石炭化度炭に加え、高水分、高灰分、低カロリーの石炭も今後使用する必要がある。今まで
は生産国内での消費が主で、国際マーケットに現れていなかったが、今後の石炭需要を考えると、使い方を考えないといけない。特に高灰分炭については埋蔵量も正確には把握されていない。
高水分炭に関しては脱水技術としての前処理が種々ある。乾燥処理は、どんな熱源を利用するか、また温度条件をどのするか等、プロセスコストを如何に抑えるかが重要。またハンドリング性改善のための褐炭前処理技術として、UBC プロセスや HWT プロセスが開発されている。さらには褐炭ガス化やコークス化の検討されている。
高灰分炭は如何に灰分を除くかがかぎとなる。燃焼は常圧流動床燃焼技術の開発がカギとなろう。また燃焼灰の有効利用も要検討課題。レアアースは取れないか調査してみるのも面白い。

31

(2)

講演 2 HWT による低品位炭利用
Speech 2 Low Rank Coal Utilization by HWT
日揮株式会社
技術開発本部技術開発部
副主任研究員上野 義基
Mr. Yoshiki Ueno
Senior Engineer,
Technology Development Department,
Research & Development Division,JGC Corporation

１．褐炭の熱水処理技術 HWT(＝Hot Water Treating)、及びスラリー化技術である CWM（Coal Water
Mixture 商品名：JGC Coal Fuel＝JCF）の紹介。
300℃、１２MPa の高温高圧化で熱水と処理することで、石炭化反応に近い条件で脱水改質が起きる。これをスラリー化することで、褐炭改質及び流体化技術を両立させる。また排水をスラリー化に利用できるなどメリットあり。技術のキーは流動性維持とスラリー安定性で、前者が粒度分布と水分配合量、後者は添加剤の選定。JCF はドライベースで原料褐炭より発熱量があがることが確認されている。褐炭埋蔵量が多いインドネシアに於いて 2011 年 11 月に 1000 トン/年のデモプラント
完成予定。
2．Q&A
Q1) CO2 の排出量はどうか、その改善方法は？
A1) 石炭と同じ状況である。改善にはいくつかの対策の組み合わせが必要。
Q2) スラリーの水分量は？
A2) 30～40%

32

(3)

講演 3 炭鉱メタンガス濃縮利用技術の紹介
Speech 3 Investigation of Clean Methane Production from Low Rank Coal
大阪ガス株式会社
エンジニアリング部プロセスチーム 兼
A-ATG プロセス PJ チーム
マネージャー
増田 正孝氏
Mr. Masataka Masuda
Manager
Process Engineering Team
A-ATG Process Development PJ Team
Engineering Department
Osaka Gas Co., Ltd.

1.

温暖化係数でCO2の3.8倍あるメタンガスのうち、炭鉱メタンガスの濃縮利用技術についての紹介。
現在未利用で大気放散されている濃度30％未満の炭鉱メタンガスは中国が最も多く、全世界では、
年間3億8000万トンに上る。大阪ガスでは吸着剤を用いたメタンガス濃縮技術を開発し、例えば、メ
タンガス濃度20％、100m3/時を45％、400m3/時まで濃縮可能である。現在中国において、回収率90％以上、ガスエンジン利用を目指したFSをおこなっており、2011年実証予定である。
石炭ガス化炉からの代替LNG生産について発表。現在インドネシア東カリマンタン地区にてLNG
生産を検討中。ガス化炉にて製造される水素及びCOをさらにシフト反応でH2とCO2を生産。CO2
はメタネーション反応により、メタンを製造。LNG精製は既存プラントが利用可能。エネルギー価格
次第では十分採算性あると見ている。課題は余剰CO2の処理、LRCの確保、他の化学品併産方法の確立、国の法規制などと考えられる。

2.

33

10)

セッション 4A(ii) 低品位炭技術 (ii)
Session 4A(ii)
Low Rank Coal Utilization Technology (ii)セッション議長
インドネシア商工会議所
常任委員会
副委員長
ジェフリー・ムリオノ氏
Session Chair
Mr. Jeffrey Mulyono
Vice Chairman,
Standing Committee,
Indonesia Chamber of Commerce andIndustry (KADIN)(1) 講演 1 インドネシアにおける低品位炭有効利用
Speech 1 Low Rank Coal Utilization in Indonesia
インドネシア商工会議所
常任委員会
副委員長
ジェフリー・ムリオノ氏（兼、バクテ・エネルギー社社長）
Mr. Jeffrey Mulyono
Vice Chairman,
Standing Committee,
Indonesia Chamber of Commerce andIndustry (KADIN)(President Director, PT Bhakti Energi Persada)

１．BEP の褐炭は水分が約 45%と高い。これを乾燥して 11%に下げることができれば、発熱量が6000kcal/kg まで改善し、PLN で使用している瀝青炭レベルとなる。また硫黄分は現状より少なくなる。従ってインドネシアで多く産出する褐炭を改質、高付加価値化することは非常に有効なことである。
主な改質技術としては、
1) BCB：粉砕褐炭を固めてブリケット化する
2) UBC：粉砕褐炭をオイルと混合。熱処理、脱水し、固める
3) K--Fuel：高温高圧処理
4) GTLEnergy：低温乾燥
5) CUB：蒸発脱水した褐炭をブリケット化がある。インドネシアは褐炭を多く産出するので、今後もこれらの技術開発が進展し実用化されることを強く望んでいる。

34

(2) 講演 2 二塔式ガス化炉による化学原料ガス製造技術
Speech 2 Twin IHI Gasifier (TIGAR) Technology for Chemical Feedstock株式会社 IHI
電力事業部
ガス化・酸素燃焼プロジェクト担当
主幹（部長）
渡辺 修三
Mr. Shuzo Watanabe
General Manager,
Gasification & Oxy-Fuel Combustion,
Power Plant Division,
IHI Corporation
IHI で開発中の TIGAR 炉の紹介。
2 段流動床を持ち、前段が Steam 改質によるガス化炉、後段が燃焼炉となる。特徴としては、粒子が熱媒体となること、常圧運転であること（フィードの昇圧が不要）、比較的低温の反応となること、総熱量が少なく済む事、バイオマスが利用しやすいことがあげられる。現在は 6 トン／日のテスト機で試験中。実用化は 300～1000 トン／日の規模となる。その際はマルチモジュール化が必要。2010 年度は主にガス精製、排水処理のテストを行ってきた。2014 年度にインドネシアで実用化を目指す。ガス化炉の水素濃度は約 50％であり、アンモニア（肥料）製造に向いている。現在インドネシアの LNG の 7％がアンモニア製造に使用されており、その代替としての用途が期待される。

35

(3) 講演 3 低品位炭技術の将来見通し
Speech 3 Future Perspective of Low Rank Coal Utilization
独立行政法人新エネルギー・
産業技術総合開発機構
環境部
主幹
矢内 俊一氏Dr. Shunichi Yanai
Director,
Environment Department,
New Energy and Industrial Development
Organization (NEDO)

１．石炭の可採年数は石油の 40 年、ガスの 60 年に比べ長いと一般に言われている。しかし石油・ガスの可採年数が一定なのに対し石炭はアジア諸国の急激な需要増に伴い、可採年数の減り方が大きい。したがって今後の需要層を考えた時、低品位炭の利用は必要不可欠なものである。
LRC は石炭化度は低い他に、灰分が多い、水分が多い等の問題があり、国際マーケットには乗ってこない。基本的には改質して地元消費となる。NEDO ではこのような見地で各種技術開発を進めてきた。
灰分：選炭技術、ハイパーコール
脱水：HWT-CWM、UBC
ガス化：EAGLE、ECOPRO、TIGAR
液化：瀝青炭液化、褐炭液化、間接液化（GTL）
コークス：ブリケット製造などがその代表例である。これら技術のインテグレーション及び既存インフラの利用が実用化のカギと
なろう。

36

セッション 4B(i) APEC エコノミーにおける CCS 開発 (i)Session 4B(i)CCS Development in APEC Economies
セッション議長
韓国エネルギー研究院
研究主幹
ビョンモー・ミン博士
Session Chair
Dr. Byungmoo Min
Principal Research Engineer,
Korea Institute for Energy Research (KIER)

11)

(1)

講演 1 日本における CCS 研究開発動向
Speech 1 Current Status of CCS R&D in Japan
財団法人地球環境産業技術研究機構
東京分室長
高木 正人氏Dr. Masato Takagi
Director
Tokyo Branch Office,Research Director,
Research Planning Group,
Research Institute of Innovative Technology for the
Earth (RITE)

1.

2.

3.

CCS の現状・ 回収は、コストとエネルギー消費が問題
・ 貯留は、技術、安全性、規制が問題。
・ わが国は、回収コストを、現在の 4200 円/トンから、2015 年に 2000 円/トン、2020 年に 1000
円/トンを目標としている。
回収技術
・ 化学吸収法は、MHI（10 トン/日）、東芝（10 トン/日）、RITE（新日鉄君津 30 トン/日の計画）で実施している。
・ RITE の方法で、現在 3000 円/トン位である。
・ メンブランによる CO2 回収法も検討している。モジュールを 350 本集めた実験をしている。
貯留技術
・ 長岡で 10,000 トンの注入試験を実施した。深さ 1100ｍで、現在もモニタリングをしている。
・ 大規模実証については、現在日本 CCS 調査㈱が磐城沖、苫小牧沖、北九州沖で調査をしており、その結果による。わが国は船による輸送を想定している。
・ 貯留コストは、1000 円/トン位である。

37

(2)

講演 2 カナダにおける CCS 開発概要
Speech2 Overview and Status of CCS Developments in Canada
カナダ天然資源総局
上級化学技術顧問
フランク・モーリツ博士
Dr. Frank Mourits
Senior Science & Technology Advisor,
Natural Resources Canada (NRCaN)

1. 背景（2） CCS の重要性について。エネルギー生産は化石燃料輸出により年 1000 億ドル以上を稼ぐ
カナダ経済の礎石であると同時に、GHG 排出削減を牽引している。
（3） カナダは野心的排出削減目標をもち、CCS プロジェクトはカナダ経済におけるエネルギー、
環境および経済の重要な要素
2. カナダの CCS イニシアティブ（6） GHG 排出削減目標は 2005 年比で、2020 年に 17％、2050 年には 60～70％削減、2020 年
までに GHG 非排出源からの電力割合を 90％とするが、これは化石燃料発電での CCS を含む。2015 年以降の新設火力は NGCC と同程度である必要、CCS-Ready は 2025 年。
（7） CCS 研究開発と実証段階。Weyburn-Midale プロジェクトでは年間 300 万トンが商業段階で、酸性ガス注入、ECBM が実施されている。パイプラインも既存設備がある。しかし、商業化に際しては、コスト、規模など多くの課題がある。
（8） CCS 政策は、研究開発、実証、国際協力、法制度などの環境整備を独立的に進めている。
（9） 1990 年に開始した 2020 年に向けた CCS 実施の統合的スケジュールが決定。年間 100 万ト
ン以上の大規模プロジェクトは 7 箇所。
（10）
知見の共有と法制度整備（11）
国内と国際的な協力関係。連邦と州政府関の CCS ネットワーク構築、米国との共同、様々な国際枠組みへの参画。
3. まとめ（1） エネルギー生産はカナダ経済の重大構成要素である（2） CCS は GHG 削減目標達成に向け戦略的重要性を有する。しかし、CCS 商業化に関連して依然として多くの課題がある。カナダは連邦と州が連携し、35 億ドルの公的資金を CCS に割り当てる。
（3） カナダは CCS 分野における世界のリーダーとして国際的に関与している。

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(3)

講演 3 韓国における CCS 開発概要
Speech3 Current Status of CCS Projects in Korea
産業科学技術研究所
研究主幹
キョンウー・ハン博士
Dr. Kynwoo Han
Senior Research Engineer,
Research Institute of Industrial Scienceand Technology (RIST)

1. 韓国における CO2 の排出
・韓国もかなり排出量が多い国である。しかも、2020 年までに倍増する。
・韓国政府が今後 5 カ年のグリーン成長計画を発表した。
・目標を達成するためには、CO2 削減に投資していかなければならない。
・2005 年比で 30％削減する計画で、4％/年で減らしていかなければならない。
2. CCS について
・2010 年 7 月 13 日に国家 CCS マスタープランを発表した。各省庁の役割が決められている。最終的には、CCS プラントの商業化である。
・回収技術に関する最初のナショナルプロジェクトも計画されている。
・製鉄過程で CO2 が大量に排出されるので、鉄鋼業において 9％削減しようとしている。
・海洋や沿岸貯留も検討している。

39

12)

セッション 4B(ii) APEC エコノミーにおける CCS 開発 (ii)
Session 4B(ii)
CCS Development in APEC Economies (ii)セッション議長
カナダ天然資源総局
上級化学技術顧問
フランク・モーリツ博士
Session Chair
Dr. Frank Mourits
Senior Science & Technology Advisor,
Natural Resources Canada (NRCaN)(1) 講演 1 ポストコンバッション CO2 分離回収技術における東芝の取り組み
Speech 1 Toshiba’s Activity in Post Combustion CO2 Capture Technolgy
株式会社東芝 電力システム社
火力・水力事業部
技監
宮池 潔氏
Mr. Kiyoshi Miyaike
Senior Fellow,
Thermal & Hydro Power Systems & Services Division,Toshiba Corporation Power Systems Company

1. 東芝の CCT(1) ポストコンバッション CCS 技術体系
(2) シグマパワー有明㈱47.5MW 三川発電所の概要。福岡県大牟田市の旧三池炭鉱自家発。
2. Mikawa（三川）PCC パイロットプラント(1) 2009 年 9 月から試験開始。47.5MW 石炭火力において、排出量の 1％（2100Nm3/hr）からアミン化学吸収法により排気中の CO2（99%純度） 90%（10t-CO2/day）を回収するもの。
(2) 2328 時間の連続運転を含み 4000 時間（2010 年 7 月 15 日で 3901 時間）運転。
(3) 試験項目は① プロセス評価② 性能試験
③ 連続運転試験④ 負荷変動試験⑤ 吸収剤性能評価
3. 実証試験（1） 回収効率（2） 吸収剤（3） 耐摩耗
4. まとめ(1) 東芝は三川発電所パイロットプラントにおいて CCS 技術商業化を実施している。

40

(2) 東芝は実際の発電所における大規模 CCS に対応できる技術を確立した。
5. Q/A(1) Kim（KEPCO）試験中の NOx、Sox、Hg 等のガス基準はどうか→試験前中後で異状はなかった。
(2) 三沢（J-Power）蒸気タービンからの蒸気抽出最適化の考え方→プラント条件により異なる。リ
ボイラーの蒸気は通常。
(3) Mourits（CANMET）コスト削減は→現段階はコスト参入要素を積み上げているため、価格も流動的であり、コスト見積もりは不確実。

(2) 講演 2 台湾における CCS プロジェクト現状
Speech 2 Current Status of CCS Project in Chinese Taipei
台湾工業技術研究所
グリーンエネルギー環境研究所
研究主幹兼チーフプロジェクトリーダー
ショーン・オウヤング氏
Mr. Shoung Ouyang
Senior Researcher and Chief Project Leader,Green Energy and Environment Laboratory,
Industrial Technology Research Institute (ITRI)

1.

CO2 貯留・地中貯留が安全かどうか。貯留の可能性について検討している。
・発電の 80％は化石燃料で、623kgCO2/kWh(2009 年)排出している。原子力は反対もある。
・現状のままでは、化石燃料は 2025 年において、CO2 を 550Mt 排出すると予測されている。
・政府の基本計画では、CCS が入っている。
・大規模貯留場所があるかどうか、塩水帯水層等を探している。
・ITRI は、14 の構造で、9000～18000Mｔの可能性を見出している。
2. CO2 回収・カルシウムループを検討しており、1 トン/日の装置を発電所に設置して試験を実施する予定である・・メソポーラスシリカによる検討も行っている。
・CCS R&D アライアンスが組織され、開発のロードマップが作成された。2014 年までパオロット、
2018 年まで大規模化、2025 年までに商業化となっている。
・CPC コーポレーションが 10 億ドル(台湾)で、台湾中央部で回収技術の実用化を進める計画である。
・中国鋼鉄も、CO2 の回収隔離は不可欠としており、加速、導入を検討している。

41

(3) 講演 3 東南アジアの天然ガス・コプロダクションにおける CO2 回収貯留技術評価
Speech 3 Assessment of the Capture and Storage Potential of CO2 Co-Producted with Natural Gas in
the South-East Asia
豪州ニューサウスウェールズ大学
石油エンジニアリング学部
上級講師
ガイ・アリンソン博士
Dr. Guy Allinson
Senior Lecturer,
School of Petroleum Engineering,
University of New South Wales (UNSW)

1. APEC プロジェクト「東南アジアにおける CO2 貯留ポテンシャル評価」(1) APEC エネルギーワーキンググループによるプロジェクト(2) 豪州 NSW 大学、CO2CRC 社、豪州石油探査生産協会 APPEA がプロジェクト参加メンバー
2. 構成(1) 本レポートは、ねらい、既存注入プロジェクト、注入オプション、評価、経済効果、事例研究、
法制度、まとめと提言で構成される。
(2) 報告書の一部を概略紹介する。
3. 目的は CCS 適用による東南アジア域の天然ガス生産と CO2 削減の実現可能性に関する技術・経済評価。調査領域は、域内の天然ガス田からのガス輸送と CO2 輸送・貯留コスト。EOR・EGR 生産増進のための CO2 注入ポテンシャル
4. 世界の既存プロジェクト（Sleipner、Snohvit、InSalah、Weyburn-Midale、Gorgon）。2008 年で 123 のEOR プロジェクト。
5. 注入オプション
6. 貯留可能性があるのは、滞水層（貯留のみであるが、貯留能力は大）、操業中のガス・石油生産井（EOR・EGR）、廃棄ガス・石油田。
7. コストと事例研究成果
8. まとめ(1) 複数の CO2 注入プロジェクトが存在する。
(2) EOR は限定的、EGR については可能性がある。
(3) 更なる調査が必要、特に EGR。詳細は Web サイト（publication.apec.org）を参照されたい。

42

(4) 講演 4 米国における CCS に関する省庁間連合タスクフォース
Speech 4 Interagency Task Force on CCS
米国エネルギー省
化石燃料局
企画・環境分析室長
ジャラド・ダニエルズ氏
Mr. Jarad Daniels
Director,
Office of Planning & Environmental Analysis,
Office of Fossil Fuel,
Department of Energy (US)

1. 気候変動における CCS の役割
CCS を実用化しないと、地球温暖化を避けることができない。
2. ＣＣＳ技術の現状
・輸送は大きな問題ではない。
・数千マイルのパイプライン輸送は問題ない
・DOE は、10 のプロジェクトを実施。
・FutureGen は酸素燃焼になった。
・貯留については、飲料水に影響がないか、特に要請されている。CO2 の隔離が必要である。
・現在の規制でどのように当てはまるか。規制を変えなければならないか。省庁による見解の違いもあり、検討中である。
・研究開発の促進のために、635M ドル拠出している・
・環境保護庁は、貯留について Off Shore でどうなるか検討している。
・いろいろな基金を作ることも重要である。
・圧入、モニタリングをして、一定の条件を満たせば、最終的に連邦政府にもどすことになるであろう。
・R&D への資金援助は必要であるので、どのような課題があるか検討して示していくことが重要。

43

13)

セッション 5 パネルディスカッション APEC 域における CO2 削減に関する方向性
Session 5 Panel Discussion Direction on CO2 Reduction in APEC Region
モデレーター
一橋大学大学院商学研究科
教授
橘川 武郎氏Moderator
Prof Dr Takeo Kikkawa
Graduate School of Commerce andManagement,
Doctor of Economics,
Hitotsubashi University

地球温暖化対策における CO2 削減は如何にトレーオフを解消するかがカギとなる。つまり豊かさと CO２の削減である。現状よりさらに気温が２度上昇すると後戻りできなくなるという報告もある。一方飢餓で亡くなる人もいる。豊かさと環境の両立のためには、日本の役割としての CCT 普及によってトレードオフの解消を目指すべきである。GDPあたり必要エネルギーは日本より高い国もある。豊かになりながら CO2 を削減するヒントが省エネである。
日本の省エネは石油危機の蓄えであり最近は停滞気味。6 月に出されたエネルギー基本計画２１
項目のうち 6 項目は発電に関するものであった。参考になる日本発アイデアは 2 件ある。一つ目は民生部門におけるトップランナープログラム。家電や自動車など最高水準を基準とする考え方。かなり成果が上がっている。二つ目は産業部門におけるセクターアプローチ。セクター毎に削減基準を決める。発電、鉄鋼、セメント、自動車で過半の削減可能。各国使用炭で再計算してもこのアプローチで省エネを進めれば 1 億トンの削減効果となる。

(1) パネリスト 1 （豪州） Panelist 1 (Australia)
豪州連邦資源エネルギー観光省
低炭素石炭政策課長
ジョン・カラス氏
Mr. John KarasManager,
Low Emissions Coal Policy Section,
Department of Resources, Energy and Tourism(DRET)

1. なぜ CCS か(1) 気温上昇を 2℃に抑制するためには、世界の GHG 排出を 2050 年に 2000 年比で 50%削減する必要がある。アジア太平洋域においては、より克服すべき課題がある。経済成長とエネルギ
ー成長の勢いが大きい。石炭依存度合いも大きい。
(2) 石炭利用拡大に伴い、排出削減量もより必要になる。より高効率火力発電が一つの回答だが、広く CCS を利用することが重要。
(3) 最大課題はタイミング44

2. トップバッター(1) それぞれの経済は独自の時間軸で CCS 導入するが、遅れはコスト上昇(2) 豪州は 2020 年から広範囲に CCS 導入が可能、早期に導入する経済は追加的なコスト負担がある。他の経済は成熟した技術が導入可能となり、コストで便益(3) 国際共同研究が CCS に関する人材育成、情報共有の場となる。
3. Q&A(1) 質問 1：経済と環境
・ APEC では現在ここまで共有化できている。この場で指示できるものはない。
・ CCS 導入は高くつくことを強調したい。トレードオフとして資源利用。
・ CO2 の再利用を考えても良い。100%は回収出来ないが、付加価値をつけることができれ
ば CCS コストは相殺。
・ CCS については中国からのニーズがあり、10 万トンプラントを建設。次は地中貯留。
・ 4B セッションの APEC の研究にもあるようにポテンシャル研究が重要。EGR も。GCCSI な
ど国際枠組みを利用。
(2) 質問 2：CCS・APEC・炭素価格
・ 既に、質問への回答はカバーされたと理解。
・ 公的資金を導入するためには、情報伝播、広く入手できるものなど条件がある
・ 炭素価格は、効果的なメカニズムとなる可能性はあり検討しているが、一方的に実施するものでない。国際合意が出来れば価格メカニズムに移行。

(2) パネリスト 2 （米国） Panelist 2 (US)
米国エネルギー省
化石燃料局企画・環境分析室長
ジャラド・ダニエルズ氏
Mr. Jarad Daniels
Director,
Office of Planning & Environmental Analysis,
Office of Fossil Energy,
Department of Energy (US)・IEA が BAU のシナリオとブルーマップのシナリオを示した。
・世界的に CCS が進まなければならない。大規模 CCS がなければどうなるか。米国議会は気候変動への対応をまだ決めていないが、待つ必要なないと思う。
・CCS は国際協力が不可欠である。
・技術だけではない。APEC で前進できる方向、APEC がどのように寄与できるか。地中モニタリング
や地上以外の貯留について検討すべき。
・公共教育が必要。
・すぐに普及できる技術が必要。
・エンジニアリングの情報共有が必要。

45

(3) パネリスト 3 （インドネシア） Panelist 3 (Indonesia)
インドネシア商工会議所
常任委員会副委員長
ジェフリー・ムリオノ氏
Mr. Jeffrey Mulyono
Vice Chairman, Standing Committee,
Indonesia Chamber of Commerce andIndustry (KADIN)

1.

2.
3.

4.
5.

どうして途上国が環境について考えなければならないか。
・
先進国の負荷によるものではないか
・
しかし、資源がなくなったらどうするか、酸素がなくなったらどうするかなどを考えると、途上国も CO2 による温暖化について考えなければいけないと思う。
インドネシアは低品位炭の利用が増えているし、石炭輸出も必要であるが、2050 年までに26％削減する計画、国際支援があれば 41％削減可能。
CO2 削減に対して、何かやらなければならないと思っている。途上国の意識改革や CO2 を出さないものづくりが必要。最後には、自分たちもやらなければならないことを教える。3 年
前と今とは違ってきた。
地球を救う話をしているので、情報を共有することが重要。この APEC の会議は情報を共有している。
炭素の取引については、インセンティブが必要。CCS の価格は、できるだけ下げる必要がある。

(4) パネリスト 4 （カナダ） Panelist 4 (Canada)
カナダ天然資源総局 上級化学技術顧問
フランク・モーリツ博士
Dr. Frank Mourits
Senior Science and Technology Advisor,
Natural Resources Canada (NRCaN)

CO2 削減に関し現状を考えると、ＡＰＥＣ域のＣＯ２の削減なしには途上国の発展はない。世界的な合意はまだないし、コペンハーゲンでも見通しはない。従って炭素に値段をつけるという行動をとらな
ければ民間は自発的にコストの上がる技術は導入しない。電力価格の上昇は必須。選択可能なプロセスとしてＣＣＳは大きな影響ある。この点で特にＡＰＥＣ化石燃料Ｇｒが貢献できるといってよい。

46

CCS は他のパネリストからの発言にもあったように、炭素の回収コストが下がらなければ実用化できない。１０～２０ドル/トンＣＯ２が目標コストと考える。先進国では次世代ＣＣＳの準備しなければならない。途上国に関しては、技術的能力の向上と資金の準備が必要。先進国はそれに関して協力をする
準備がある。
最初に出来ることはＣＣＳトレーニングのワークショップをすることであろう。ＣＣＳの認知度を高め、回収、貯蔵、輸送、現場技術トレーニングなど国での教育が大事。カナダではＩＥＡワークショップが 2
年前に開かれた。
小規模ＣＣＳでもまずは実行が大事。ＦＳも大事。法規制の枠組み論議が必要。ＡＰＥＣ諸国でも一般の人々がＣＣＳの利益を認識できるように。ロッテルダムでは反対デモが起こった。これは CCS の認知が上手くいかなかった失敗例である。今後はうまく認知度を高めないとならないと思う。

(5) パネリスト 5（日本） Panelist 5 (Japan)
経済産業省資源エネルギー庁
資源・燃料部石炭課長
橋口昌道氏
Mr. Masamichi Hashiguchi
Director, Coal Division,
Natural Resources and Fuel Department,
Agency for Natural Resources and Energy(ANRE),
Ministry of Economy, Trade and Industry(METI)
1. エネルギー資源のなかでの石炭の役割(1) 1990 年比 2020 年で GHG25%削減目標、国際枠組みでの役割は検討。
(2) 3E 同時達成に向け石炭のクリーン利用が課題。国内炭は 1%未満で石炭は 1.65 億トン消費しており日本は利用専門家。高効率（42%）石炭火力と高効率の長期間維持技術が強み。エネル
ギー基本計画では低炭素社会研究開発と国際展開、安定供給面では低品位炭の効率的、有効利用が強調。
2. 石炭火力発電分野における低炭素化(1) 国内石炭火力の更なる高効率化・低炭素化とゼロエミッション化。大崎 CoolGen 計画をすすめ、
ゼロエミッションにむけた CCS 実証を豪州と共同研究(2) 高効率石炭火力発電技術移転による低炭素化。世界の石炭火力発電市場は 2030 年に倍増の見込み。海外石炭火力への CCT 技術移転による GHG 削減効果は日本経済の CO2 排出量に相当する試算。
(3) 現行 CDM は対象分野や垣根があり限界、二国間オフセットメカニズムの仕組みを提唱
3. 石炭の安定供給（1） 世界的な石炭需要拡大のなかでインフラが重要課題。主要石炭生産経済との政策対話を通した協力関係構築（2） 低品位炭の効率的利用
4. Q&A(1) 質問 1：経済と環境

47

・優先度合いからは IGCC+CCS。CCS に関して海底下貯留候補地を研究しているが、国土が狭く、適地が見えない。高効率化を進めているが、CO2 分離回収にも重点をおく。化学・物理的の各方法に強みと弱みがある。
・APEC には、年一回情報共有の仕組みが出来ている。CO2 排出削減への意識を高めることに有効だが、NOx・SＯx 対策も重要と考える。
(2) 質問 2：CCS・APEC・炭素価格
・地中はよくわからないため基礎調査が重要。GCCSI など設立されたことは有意義・APEC には情報共有、グローバルな考え方を持つ場
・炭素価格については、デリケートな問題で、研究開発を重要視し、進んだ段階で議論。

(6) パネルディスカッションの討論
 Q1） 橘川教授からパネリスト全員に質問：「豊かさと CO2 削減のトレードオフ。APEC として最も高いと思う対策は何か？」カラス氏） 我々がどうするか命令するものではない。この場では情報を共有化したい。CCS の
現状コストは高いし、トレードオフとして資源を使う。各国で CCS 導入のために何が出来るか、また再利用も考えないといけない。CO2 に付加価値をつけることが出来ればコストをカバーすることができる。発電からの CO2 を回収して産業界からのサポートを得ることが出来る。中国で発電所の CCS 例がある。発電会社でもサポートしていた。多サイトでも展開中。フルス
ケール地中貯留も検討中。豪州も協力を考えている。LNG 回収 CO2 の CCS ではニーズがある。CO2 分離回収コストも重要なファクターである。APEC 域で有効なプログラムとなればよい。
ダニエル氏） カラスさんの考え方は良いがすべてがフィットするわけではないので、サマース
クールのような教育活動を APEC でやるのはどうか。一般に認識してもらう行動、教育が大事ではないか。それぞれの活動の中で何が最善かを各国レベル考えればよい。APEC はネッ
トワーク活動の場として専門的な立場から貢献できる。共有化を助ける対話の場として。日本が言っている効率改善は、性能向上、効率改善、運用保守も大事。APEC の場で各国に働きかけてほしい。標準化。
ムルヤノ氏） インドネシアの観点では新しい発電所は種々考慮がされている。環境規制も大事だが、コストも問題なので、まずは意識を変えることが重要。特に途上国では大事。CO2 排
出のない方法はないか？インドネシアは総排出量が少ないので意識が低い。次世代に向けた教育で意識改革が必要。他国との協力も大事。
モーリッツ氏） 他の人が言ったことの繰り返しだが。CO2の再利用、EOR などの活用もふくめた中でプロジェクトを進行させることが重要。皆さんにも有意義だと思う。効率向上も大事。専門家ではないが我々が「行ってきた技術報告のなかでかなりノウハウがある。今後は情報のア
クセス機会を増やす。
橋口氏） CCS は IGCC の組み合わせで技術開発中。日本では海底貯留を検討している。日本は狭いので適地がない。日本は得意とする IGCC で貢献していきたい。分離技術は大切。
APEC それぞれ石炭に対する歴史があり、得手不得手がある。その中でどう情報を共有化して協力つなげていくかを議論したい。情報共有できる仕組みが必要。NOxSOx もある。その観点も含めてネットワークを考える必要ある。
 Q2） 各国が CCS 技術を開発しているが、この技術は競合しており、さらには他の技術が含まれているので技術の展開が難しい。APEC は技術情報提供だけなのか？（CCS 技術を APEC
域に展開させるのに）何か良い手立てはあるのか？APEC の果たす役割は何か？

48

Q3） 現在CDMについての関心が弱まる中で、排出権の二国間取引に考えが移っている。また CCS に関し楽観的に見ているように思われる。今後の見通しとして CCS は楽観視できるのか？
 Q4） 石炭火力の効率改善は必要だが、CCS はとらなければならない方策と考える。一方日
本の産業では国際的競争力を失うので好ましくないと思っている。国際的な炭素価格のつけ方ではどう思うか。
（以上をふまえて各パネリストから順番に回答）
橋口氏） CCS は楽観的とは思ってない。技術的な地価貯留はまだわからない問題もある。楽観していないがマストの問題である。APEC は地球規模で考えていく必要があるので APEC は情報共有の場。炭素価格論議は微妙な問題。まずは技術開発を進めて慎重に議論すべき。
モーリッツ氏） 情報発信について APEC は最適組織だとは思わない。継続的な関与・分析・フォローが必要なので、地球規模の組織と最新データバンクを新たに作るのが良いのでは。炭素
価格は各国のコミットメントによるので議論自体が難しい。CCS 技術が安くなれば問題でなくない。
ムルヤノ氏） 人間は高慢に成りがち（情報独占が良くないという意味か？）。情報の共有が一番良い。共有化すれば地球規模で技術開発が早く進む。炭素価格はインセンティブ必要。CCS
コストの問題。コスト問題が解決しなければ見通しが悪くなる。
ダニエル氏） 情報共有についてはたくさんの場がある。商業ベースに乗るのはGCCSI かAPEC
かはわからないが APEC では次世代技術に特化して推進すべき。京都後の課題については
個人的コメントとして楽観的には見ていない。アメリカとして言えないのは、コストは国内問題となるので慎重にする必要がある。コストが下がればアメリカは CCS に向かう。他の選択肢はいらない。
カラス氏） 豪州政府が資金を出す条件は情報の伝播。広範になる技術であれば資金を出す。
現在の日豪の共同プロジェクトは情報共有で少し弱い。まだたくさんやるべきことが残っているが GCCSI の役割の確立、プロジェクト支援を約束している。APEC の場は情報共有として良い場である。一般に情報発信してほしい。国際社会は目標達成に出遅れている。いまは個々の国で取り組んでいるに過ぎない。豪州でも高い目標であるが、かなりドラスティックな手段が必要。炭素価格に関しては国連などでかなり強力な決議があればそちらに向けて動けると思う。
(7) モデレーターによる纏め
APEC ｴﾘｱが CO2 削減にむけ重要である認識は共有できた。時間軸として高効率化は技術出し手と受け手が WINWIN になる仕組みを作ることが大事。CCS はコスト削減が必須。価値を高めるのはEOR との結合が大事。今の議論は APEC 枠を超えてやらなければならない。本議論は APEC 発、
APEC 越えの重要な議論である。

49

14)

閉会の辞 Closing Remarks
APEC 化石燃料専門家会合グループ議長
スコット・スマウス氏
Mr. Scott Smouse
Chair, APEC EGCFE

情報を普及することが必要であり、今回のセミナーは、CCTとCO2削減、CCSの重要性の情報が発信できたと思う。石炭はなくならない、長期的にも必要。石炭はきちっと使えば被害は起きないことを示す
ことが重要である。CO2を削減すれば、石炭を使っていくことができる。風力やバイオマスにも反対する人はいる。どのようにエネルギーを使うかについては、対話が必要。政策決定者だけで決めてほしくない。開かれたコミュニケーションが必要。クリーンなエネルギーを使って経済発展することが重要。よりクリエイティブなアイデアを出してほしい。

50

３． テクニカルツアー概要

51

3. テクニカルツアー概要（実施日

平成 22 年 10 月 29 日（金））１． 見学者 約 40 名
大型バス 1 台にて、ヒルトン福岡シーホーク
を出発し、電源開発株式会社若松研究所着
後、マイクロバス 3 台に分乗の上、施設を見学した。
２． 見学先 電源開発株式会社若松研究所
３． 研究所概要
毎回セミナーの最終日である 3 日目に、開催国の石炭の利用に関し認識を深めるべく、見学会が実施されている。本セミナーにおいては福岡市から日帰りでバスで移動できる
CCT 関連施設への見学として、J-POWER（電源開発株式会社）若松研究所の IGFC プラ
ントの見学を実施した。
研究所の概要は以下の通りである。
日本における石炭ガス化発電技術の開発～酸素吹石炭ガス化複合発電（IGFC）(パイロット設備)■ 多目的石炭ガス製造技術(EAGLE)■ 石炭使用量：150 トン/日
■ 試験: 2001 年度～ 2009 年度 (予定)（2007 年度から CO2 回収試験開始）■ 実施主体: J-POWER（電源開発株式会社）■ 酸素吹石炭ガス化
特色；酸素吹石炭ガス化技術の多様性
 酸素吹石炭ガス化技術は、IGFCに至る「高効率発電技術」、石油代替の「合成燃料」、「水素製造」、効率的な「CO2分離回収」など多様な用途に展開が可能な技術である。

52

前述は、酸素吹石炭ガス化（EAGLE 型石炭ガス化）技術の多様性を示したものである。
IGCC、IGFC に至る「高効率発電技術」への適用の他、石油代替の「合成燃料製造」
や「水素製造」、効率的な「CO2 回収」等多様な用途に展開できるポテンシャルを有している。このような視点から、将来の石炭の多目的利用につながるキー・テク
ノロジーとしても、石炭ガス化技術が注目されている。

参考資料；本見学会で使用された説明資料

53

54

55

56

57

４．見学会の様子

笹津若松研究所所長からの説明

若松研究所の様子

見学会参加者58

４． APEC 地域における石炭需給動向59

4. APEC 地域における石炭需給動向
世界の石炭需給動向(1)1) 世界の石炭需給動向① 世界における石炭消費動向 褐炭を含む世界の石炭消費は、2003 年以降アジア地区において急速に拡大し、2009 年には 68 億トンまで増加した。
 ここ 10 年間において、石炭の消費（含、中国及びインドの褐炭）は、2.5 倍にまで増加した。
Mt

Ratio in 2009

7,000
Mｔ
Others
20.9%

17.7％

6,000
AfricaLatin America/Middle East
14.4％

5,000
4,000
Europe/Former USSR

Japan
2.4%
South Africa
2.6%
Russia3.0%
Germany
3.3%

3,000

China
27.2%

Others
27.7%

China
45.2%

Outer Circle(2009 Estimated)
Japan
Inner Circle
3.2%
South Africa(1999)
3.5%
Germany
Russia
5.1%
5.0%
India
India
7.8%

USA
20.7%

9.2%

North America
2,000

1999

2009
Estimated

China1,229.0

3,085.6

USA

934.6

920.8

India

350.2

626.4

Germany

229.6

223.4

Russia

226.2

203.7

South Africa

156.5

180.6

Japan

142.6

164.8

Others1,249.4

1,428.2

World4,518.1

6,833.5

Asia

1,918.4

4,253.8(42.5%)(62.2%)

USA
13.5%

64.3％

1,000

Asia/Pacific0'81 '83 '85 '87 '89 '91 '93 '95 '97 '99 '01 '03 '05 '07 '09*

② 世界における石炭生産 世界における石炭の生産量も、石炭の需要拡大に伴い、2003 年以降 APEC 地域において急速に拡大し、2009 年には APEC 地域は世界の石炭生産量の 63.2%を占める程になった。
 世界における石炭の 3 大生産国は、中国、米国、そしてインドであるが、これらの国
は石炭の大きな消費国でもある。これら 3 大生産国に次いで、石炭の輸出国でもある
豪州及びインドネシアの石炭生産量が多い。
Mt

Ratio in 2009

7,000
16.6％

6,000
AfricaLatin America/Middle East
15.3％

5,000
4,000
Europe/Former USSR

Indonesia
4.4%

3,000

Australia
5.8%

North America

1,000South Africa
3.6%
Russia
4.3%

2,000

Mt

Others16.5%
Others24.6%

5.0%

Inner Circle
Russia(1999)
5.2%
Indonesia
Australia
1.6%
6.5% India
7.2%
India

8.1%

63.2％
Asia/Pacific0'81 '83 '85 '87 '89 '91 '93 '95 '97 '99 '01 '03 '05 '07 '09*

60

China
27.6%

Outer Circle
South Africa (2009 Estimated)

USA
14.3%

USA
22.2%

China
43.0%

1999

2009
EstimatedChina1,238.1

2,971.4

USA

996.1

984.5

India

323.6

560.8

Australia

291.0

399.2

Indonesia

73.8

301.5

Russia

235.2

296.8

South Africa

223.5

247.3

Others

1,103.2

1,141.2

World4,484.5

6,902.8

Asia

1,709.2

3,958.2(38.1%)(57.3%)

③ 世界における石炭貿易 世界における石炭の輸出量は、石炭の需要拡大に伴い拡大しているが、2009 年の石炭輸出量の合計は約 300Mt であった。2008 年の秋以降の世界的不況により、ほぼレベルオフ状態であった。

50

900

45

645

601

561

468

473

426

363

346

366

298

322

255

254

290

400

282

500

520

600

685

35
711

40

700
686

800

30
25
20

300

15

200

10

3,000

2,971
22.8
0.8%

2,500
Export/Production ratio (%)

Amount of export (Mt)

Mt
1,000

2,000

upper： production
middle：export
lower： ratio of export / puroduction

1,500

232

259

240

221

213

198

196

188

201

189

185

199

186

195

196

196

186

203

202

1,000

100
0

Amountof Export

919
53.4
5.8%
526
2.2
0.4%

5

335
262

500

78.1%

0
'91

'93

'95

'97

'99

Coking coal
Export/Production ratio (all of coal)
Export/Production ratio (steaming coal)

'01

'03

'05

'07

263
247
229
230
67
116
87.2% 27.1% 50.8%

'09*

0

Steaming coal
Export/Production ratio (coking coal)

in
Ch

a

A
US

d
In

ia
Au

al
str

ia
do
In

ne

sia
S

th
ou

r ic
Af

a

ia

ss
Ru

④ 主要な石炭輸出入国
 世界における主要な石炭輸出入国の傾向は次の通りである。
輸出国；第一位 豪州（約 260Mt）
第二位 インドネシア（約 240Mt）
第三位 ロシア（約 120Mt）（2004 年以降中国に逆転）
輸入国；
第一位 日本（約 160Mt）
第二位 中国（約 140Mt）（2008 年に第二位に浮上）
第三位 韓国（約 100Mt）（2008 年に中国に越された）
Mt

Mt

Australia

200

Japan

250
China

indonesia
Russia

200

150

Korea

India

Colombia
150
South
AfricaChineseTaipei100

Germany

USA.
100

UK

Canada50
Russia50

Vietnam
USA

China
0
'91

'93

'95

'97

'99

'01

'03

'05

'07

'09*

61

0
'91

'93

'95

'97

'99

'01

'03

'05

'07

'09*

⑤ APEC 地域における石炭需給動向
 APEC 地域の石炭消費量は世界の 70％以上を占めており、経済成長に伴い拡大している。尚、石炭消費量は石炭生産量を超えている。
 石炭消費量の 65%以上は、電力部門である。
Mt
80%

6,000

Mt

Production
Consumption
Production ratio (APEC / World)
Consumption ratio (APEC / World)

5,000

5,000

75%

70%

4,000

4,500
4,000

Others3,500

Commercial

3,000
Residential

65%

3,000

2,500
2,000

Generalindustries

1,500

Power

60%

2,000

1,000

Iron & steel

55%

1,000

500
0

50%

0
'91

'93

'95

'97

'99

'01

'03

'05

'07

'00 '01 '02 '03 '04 '05 '06 '07'09*2) 世界の石炭需給見通し
以下は、全て財団法人日本エネルギー経済研究所による 2009 年世界及びアジア地域のエネルギー見通しによるものである。
① 世界におけるエネルギー見通し
 世界のエネルギー消費量は、レファレンスケース予測においては 2035 年までに50％以上拡大する。
 世界的に化石燃料に依存している比率は大きく、その比率は 2007 年に 88.4%で、2035 年には 85.2%になると予測されている。石炭の比率は、2007 年では 28.8%、2035 年には 26.6%になると予測されている。
Btoe

Btoe

20.0

7.0

Others
Hydro
Nuclear

15.0

6.0
5.0

Oil

4.0

Coal

10.0

5.0

Natural Gas

3.0

Oil

2.0

Natural Gas

Nuclear
Others

1.0

Coal
0.0
1971

1980

1990

2000

2010

2020

2030 35

62

0.0
1971

1980

1990

2000

2010

2020

H ydro2030 35

② APEC 地域におけるエネルギー見通し
 人口増加に伴うアジア太平洋地域におけるエネルギー需要は、急速に拡大しており、そのエネルギー消費量は、電力化・車社会化の影響を受け、リファレンスケースにおいて 2035 年までにはほぼ 2 倍化すると言われている。
 石炭は、熱や電力のもととなる主要燃料であり続けることであろう。
Btoe

Btoe

10.0

3.5

Others
Hydro
Nuclear

8.0

3.0

6.0

Oil

2.0

Natural Gas
4.0

Coal

2.5

Natural Gas

1.5

Oil

1.0
2.0

Coal

Nuclear
Others
Hydro

0.5

0.0

0.0
1971

1980

1990

2000

2010

2020

2030 35

1971

1980

1990

2000

2010

2020

2030 35③ 世界における燃料別発電電力量見通し
 石炭は、発電電力量において主要な燃料であり続けている。
 石炭火力発電による CO2 排出量は、全世界の CO2 排出量の 30%を超えている状態である。それは、2007 年から 2035 年の間に、8.2Gt から 12.6Gt まで増加するであろう。石炭は、高効率に利用することにより、温暖化問題を解決するための重要な役割を
果たす。
TWh

TWh

40.0

16.0

35.0

14.0

Others
Hydro
Nuclear

30.0
25.0

12.0

Coal

10.0
8.0

20.0
15.0

Natural Gas

6.0

10.0

Oil

4.0

5.0

Natural Gas

Hydro
N uclear
O thers
O il

2.0

Coal

0.0

0.0
1971

1980

1990

2000

2010

2020

2030 35

63

1971

1980

1990

2000

2010

2020

2030 35

④ APEC 地域における燃料別発電電力量見通し
 APEC 地域において、石炭は、発電の主要燃料となっている。その比率は、今後 10 年
以上においても高い比率を占めることになるであろう（50%以上）。
 石炭火力発電所における CO2 排出量は、全世界的な排出量の 38%を占める。2007
年から 2035 年の間には、5.7Gt から 8.7Gt に拡大するであろう。
2007 2035%%
Coal
53.1 51.5
Oil
3.9
2.0 Others
Natural Gas 16.0 18.3 Hydro
Nuclear13.0 12.6 Nuclear
Hydro
12.2 10.1
Others
1.8
5.5
Total
100.0 100.0
Natural Gas

TWh

22.0
20.0
18.0
16.0
14.0
12.0
10.0
8.0
6.0
4.0

2007 → 2035

TWh

12.0

Coal
Oil
Natural Gas
Nuclear
Hydro
Others
Total

10.0
8.0
6.0

Oil

4.0

Coal

2.0

%
177
96
208
176
151 Coal
539
182
Natural Gas

Nuclear

Hydro

2.0

Others
Oil

0.0

0.0
1971

1980

1990

2000

2010

2020

1971

2030 35

1980

1990

2000

2010

2020

2030 35⑤ 世界及び APEC 地域における燃料別発電電力量見通し
 石炭火力発電所は、経済成長に伴い、世界的にもアジア地域においても、必須の電力供給源である。

60

%

60

%
Coal-fired

Coal-fired

40%

40

26%

30
Hydro

13%

10

NuclearOil-fired
Other Renewables

0
1980

40
30

Gas-fired

20

1971

51%

50

50

1990

2007

2010

2020

2030

12%
6.5
3.0
%
%

2035

64

20

18%

Gas-fired

Nuclear 13%
10

Hydro

10%
5.5%
2.0%

Oil-fired
Other Renewables

0
1971

1980

1990

2007

2010

2020

2030

2035

3)

世界における石炭需給動向①

世界における地域別石炭需給見通し
 2007～2035 年における全世界の石炭需要の 90%は、アジア地域が占めている。
2035 年の石炭の需要量の中でアジア地域が占める比率は、全体の 67%と予測されている。
 2007～2035 年における全世界の CO2 排出量の 35%は、アジア地区における石炭燃焼と予測されている。環境と調和した石炭利用がアジア地域において極めて重要な課
題である。
Mtoe

5000

Increase from 2007 to 2035

1174

4000

90%

3000

88

-105

N.America

-8%

7%

Asia

Europe1.3 bil. toe

8%

Other

10%

147

11%
Other

Europe6%

N.America

17%
2000

18%

1000

58%

15%

67%

0
1971

1980

1990

Asia

2007

2020

2030 2035② アジア地区における石炭需給見通し
 石炭は、増加する電力需要に対応するため、電力分野において今後も使われることが予測される。特に、国内に豊富な埋蔵量をも持つ中国、インドにおいて、その比率は今後も極めて高い。

3500

Mtoe
AAGR
1980-2007
2007-2035

3000
2500
2000
1500
1000

China India Japan Korea Taiwan Singapore
5.4% 5.9% 2.5% 5.4% 9.2% 3.9%
1.3% 3.4% -0.6% 1.2% 1.0%
Indonesia Malaysia Philippines Thailand Vietnam Other Asia

22.1% 22.1% 11.1% 13.5%
3.9% 4.6% 5.6% 4.7%

China
Japan
Taiwan
Malaysia
ThailandSingapore
Other Asia

India
Korea
Indonesia
Philippines
VietnamHong Kong

6%

-0.6%
3.5%

Japan
India

3%
20%

13%
61%

China
70%

500
0
1971

5.6%
6.3%

1980

1990

2007

2020

65

2030 2035

(2)1)

CO2 削減の可能性
先進的技術による CO2 排出量削減
 積極的に技術革新をすることにより、エネルギー消費における CO2 排出量を削減することができる。

【需要側の技術開発】
産業分野～鉄鋼業、セメント、紙パルプ業、石油精製業のような産業過程におけるBest Available Technology の適用
輸送分野～クリーン・エネルギー利用の拡大（高効率燃料車、ハイブリット車、プラ
グインハイブリット車、電気自動車、燃料電池車）
民生分野～効率的な家電製品（冷蔵庫、テレビ等）、高効率暖房システム（ヒートポンプ等）、効率的なエアコンシステム、効率的な照明、断熱設備【供給側の技術開発】
再生可能エネルギー～風力、太陽光発電、CSP、バイオマス発電、バイオ燃料
原子力～原子力発電の推進、原子力発電所の稼働率アップ
高効率化石燃料発電所～石炭火力発電所（USC、IGCC、IGFC）の拡大化、天然
ガス MACC 発電所
CCS～発電所（石炭火力、ガス火力）や産業分野における導入

66

2)

石炭火力発電所の高効率化
 先進的技術シナリオにおいては、Reference シナリオと比較して、効率向上により、
更に 1.0Gt は削減できると予測される。

4540Power Generation Efficiency、％

35

39

OECD
36

36

39

42
41
40

36

World

32

28

Non-OECD

30

40

38

34

33

41

25
1990



2007

2020

2030

2035

2007 年の世界の石炭火力の平均効率は 34%であるが、2035 年においては、
Reference シナリオでは 41%（7 ポイントアップ）、先進的技術シナリオでは 45%（11 ポイントアップ）と予測。

67

3)

CCS
2020～2035 年の間に 14Gt の CO2 が削減されると予測され、地質構造学上、CCSの理論上の可能性は、10 兆 t と言われている。採掘後のガス田、油田、炭田の１兆 t
は、先進的な技術シナリオにおいて CO2 貯留に充分適した場所と言える。

3

Gt-CO2

2.6
0.4

2

0.0
0.1

1

0.1

0.4
0.1
0.3

2020

2025

0

4)

1.0
0.2

2.2

0.8
2030

2035

世界における CO2 削減技術
省エネ、高効率発電技術の強化、再生エネルギー、原子力、燃料転換、並びに CCSを複合的に使うことにより、CO2 を大幅に削減することができる。これらの技術を使うことにより、2035 年までに 12Gt の CO2 を削減できる。
45

Gt-CO2

40

Energy Saving (46%)
Reference
Bio-fuel (4%)
PV, Wind etc. (6%)
Nuclear (10%)
Fuel Switching (12%)
CCS (21%)35
30
Tech. Adv.

Gt

25
20
1990

2007

2020

68

2035

Energy Saving
Bio-fuel
PV, Wind etc.
Nuclear
Fuel Switching
CCS
Total

6
0
1
1
1
3
12

Share
46
4
6
10
12
21
100

5)

アジア地域における技術による CO2 削減技術
先進的技術を導入することにより、アジア地域において、2035 年までに 6.8Gt の CO2を削減することができる。

6)

APEC 地域における CO2 排出量
Reference シナリオにおいて、CO2 排出量は、2035 年には 7.2Gt から 23.8Gt まで拡大すると言われている。また、石炭自身の CO2 排出量は、CO2 排出量全体の半分にと言える。
先進的技術シナリオにおいては、CO2 排出量は、2035 年までには 1.2Gt から 17.7Gtまで拡大すると言われている。
石炭自身の CO2 排出量は、増加傾向にある。

69

7)

先進的技術による石炭の CO2 排出量削減
石炭起源の CO2 排出量は先進的技術の導入と開発により、大幅に削減できる（高効率技術と CCS）。

Gt-CO220

15
Reference Case

10

12

9
8
Advanced Technology Case

5

0
'71

8)

'80

'90

'00

'07

'20

APEC 地域における石炭からの CO2 排出量
Reference Case によると、中国の CO2 排出量は、石炭の消費に伴い着実に増加する。また、米国の CO2 排出量は殆ど変わらないであろう。APEC 地域においては、中国と米国の CO2 排出量が 70%を占めるであろう。
先進的技術シナリオによると、中国の CO2 排出量は、Reference シナリオに比べ、2035 年には 2.4Gt 削減することができる。

70

'30

'35

9)

纏め
化石燃料の消費は、今後 10 年以上は拡大し続けるであろう。
石炭は、その価格安定性及び供給の持続性から、高い環境負荷があるにもかかわらず、主要なエネルギー源として残り続けるであろう。
APEC 地域において、石炭は、2035 年のエネルギーシェアで高い比率を占める。
Reference シナリオでは 36%、先進的技術シナリオでは 32%を占めると予測される。
そのためには、下記のような政策が必要である。
【課題】

【対策】

CO2 排出量削減

・高効率技術
SC、USC の導入
より高効率技術の開発
・CCS

大気及び環境汚染

・既存の CCT をより浸透させること需要拡大に対する
持続的供給

・・低品位炭の活用による高効率技術の開発

71

資料集

１． セミナープログラム

資料1

Final Schedule

New Developments in Clean Coal and
CO2 Reduction Technologies
APEC Clean Fossil Energy Technical and Policy Seminar 2010

FINAL ANNOUNCEMENTHILTON FUKUOKA SEA HAWKFUKUOKA, JAPAN
27-29 OCTOBER 2010
ORGANIZED UNDER THE DIRECTION OF THE
APEC EXPERT GROUP ON CLEAN FOSSIL ENERGY (EGCFE)STEERING COMMITTEE
Japan: Ministry of Economy, Trade and I ndustry (METI)
USA: Department of Energy (DOE)
Canada: Natural Resources Canada (NRCan)
Australia: Department of Resources, Energy and Tourism (DRET)SEMINER SECRETARIAT

Japan: New Energy and Industrial Technology Development Organization (NEDO)
Japan Coal Energy Center-Japanese Center for Asia Pacific Coal Flow (JCOAL- JAPAC)SPONSORED BY:
Japan: Ministry of Economy, Trade and I ndustry (METI)
USA: Department of Energy (DOE)
National Energy Technology Laboratory (NETL)
Canada: Natural Resources Canada (NRCan)
Australia: Department of Resources, Energy and Tourism (DRET)

資料2

Day 1

October 27, 2010 (Wednesday)

08:30-9:00 Registration
MC (Japan) Mr. Nobuyuki Hara, Director, Environment Department, New Energy and Industrial Technology
Development Organization (NEDO)
09:00-10:50 Opening Session
Chair: (Japan) Mr. Sadao Wasaka, Executive Director, New Energy and Industrial
Technology Development Organization (NEDO)
09:00-09:10 Opening Address
Mr. Scott Smouse, APEC EGCFE Chair
09:10-09:20 Welcome Remarks 1(Japan) Mr. Hisayoshi Ando, Director-General, Natural Resources and Fuel Department,
Agency for Natural Resources and Energy (ANRE), Ministry of Economy, Trade and Industry (METI)
09:20-09:30 Welcome Remarks 2(Japan) Mr. Wataru Aso, Governor, Fukuoka Prefecture
09:30-09:50 Featured Speech 1 Coal Policy and Contribution forwards CO2 Reduction in the World(Japan) Mr. Hisayoshi Ando, Director-General, Natural Resources and Fuel Department,
Agency for Natural Resources and Energy (ANRE), Ministry of Economy, Trade and Industry (METI)
09:50-10:10 Featured Speech 2 The Role of Coal in a Low-Carbon Future(IEA) Mr. Bo Diczfalusy, Director, Directorate of Sustainable Energy Policy and Technology,
International Energy Agency(IEA)
10:10-10:30 Featured Speech 3 CCS Development Status(US) Mr. Jarad Daniels, Director, Office of Planning & Environmental Analysis, Office of Fossil Energy,
Department of Energy (DOE)
10:30-10:50 Special Report Outlook of Coal Demand/Supply and Countermeasures towards CO2
Reduction in t he APEC Region(Japan) Mr. Atsuo Sagawa, Senior Analyst, Coal Group, Strategy and Industrial Research Unit,
The Institute of Energy Economics, Japan(IEEJ)
10:50-11:10 Coffee Break

11:10-11:55

11:10-11:25

11:25-11:40

11:40-11:55

Session 1-A: Coal Policy in the APEC
Economies(i)Chair: (Korea) Dr. Jiho Yoo,
Senior Research Engineer,
Korea Institute of Energy Research (KIER)
Speech 1: Coal Demand & Supply in Canada(Canada) Dr. Frank Mourits, Senior Science &Technology Advisor, Natural Resources Canada(NRCan)Speech 2: Coal Policy and CO2 Reduction in
the Philippines(Philippines) Ms. Alicia N. Reyes, Director of theDevelopment
andEnergyResources
Management (ERDB), Department of Energy(DOE)
Speech 3: Coal Policy and CO2 Reduction in
Korea(Korea) Dr. Sungchul Kim, Project Leader,
KEPCO Research InstituteSession 1-B: Coal Policy in the APEC
Economies(ii)Chair: (Japan) Mr. Masamichi Hashiguchi,
Director, Coal Division, Natural Resources andFuel Department, Agency for Natural Resources
and Energy (ANRE), Ministry of Economy,
Trade and Industry (METI)
Speech 1: Coal Policy and CO2 Reduction inAustralia(Australia) Mr. John Karas, Manager, Low Emissions
Coal Policy Section, Department of Resources,
Energy and Tourism (DRET)
Speech 2: Coal Policy and CO2 Reduction inIndonesia(Indonesia) Mr. Tri Winarno ST MT,
Head of Mineral Standarization, Directorate Generalof Mineral and Coal, Ministry of Energy and Mineral
Resources(MEMR)
Speech 3: Coal Policy and CO2 Reduction in
Thailand(Thailand) Dr. Boonrod Sajjakulnukit, Lecturer, King
Monglut’s University of Technology Thonburi(KMUTT) (former Senior Official, Ministry of Energy)

11:55-13:30 Lunch
13:30-13:50 Featured Speech 4: Clean Energy in Asia
(Japan) Prof Dr. Hideo Nagashima, Vice President, Kyusyu University
13:50-15:10 Session 2: CO2 Reduction by Diffusion of High-Efficient Coal-Fired Power Generation (i)Chair: (Japan) Mr. Masaki Nakatsuka, Director, Environment Department,
New Energy and Industrial Technology Development
Organization (NEDO)
資料3

13:50-14:10 Keynote Address1; Japan’s Role for solving the Environmental Issues in APEC region(Japan) Mr. Yoshihiko Nakagaki, Chairman, Japan Coal Energy Center (JCOAL)/
Corporate Adviser, J-Power
14:10-14:30 Speech 1: Introduction and the Issues of USC Technology in China(China) Ms. Xiaolu Zhang, Vice President, China Power Investment Corporation (CPI)
14:30-14:50 Speech 2: Introduction and the Issues of USC Technologies in Korea(Korea) Dr. Seonman Loh, General Manager, Power Department, Korea South-East Power Company(KOSEP)
14:50-15:10 Speech 3: CO2 Reduction by Development of High-Efficient Coal-Fired Power Generation in
Japan(Japan) Mr. Kazuhiro Izaki, General Manager, Thermal Power Department, Thermal Power Generation
Division, Kyushu Electric Power Co., Ltd.

15:10-15:30 Coffee Break

15:30-15:50 Featured Speech 5: ADB’s Support towards Efficient Coal-Fired Power Generation(ADB) Mr. Jong-Inn Kim, Lead Professional(Energy), Sustainable Infrastructure Division, Regionaland Sustainable Development Department, Asian Development Bank (ADB)

15:50-16:30 Session 3: CO2 Reduction by Diffusion of High-Efficient Coal-Fired Power Generation (ii)
Chair: (Australia) Mr. John Karas, Manager, Low Emissions Coal Policy Section, Department of
Resources, Energy and Tourism (DRET)
15:50-16:10 Speech 1: IGCC and ICS – Advanced Technology from Japan to the World– From Demonstratio to Commercial Application (Japan) Mr. Takao Hashimoto, General Manger, IGCC & Gasification Business, Power Systems HQ,
Mitsubishi Heavy Industries, Ltd. (MHI)
16:10-16:30 Speech 2: Overview of US Gasification Program(US) Mr. Scott Smouse, International Group Leader, US Department of Energy (DOE),
National Energy Technology Laboratory (NETL)

16:30

Day 1 Adjourns

17:30-20:00 O fficial Welcome Dinner

資料4

October 28, 2010 (Thursday)

Day 2
08:30-09:00 Registration

09:00-09:20 Featured Speech 6: Support towards CCS Demonstration Project by GCCSI(GSSCI) Mr. Mark Bonner, Senior Specialist, Policy and Strategy, Global CCS Institute09:20-10:20

09:20-09:40

09:40-10:00

10:00-10:20

Session 4-A (i): Low Rank Coal Utilization
Technology (i)Chair: (Japan) Prof Isao Mochida,
Kyushu University
Speech 1: Introduction to Research andDevelopment on the Efficient Utilization of
Low Grade Coal
(Japan) Prof Isao Mochida, Kyushu University

Session 4-B (i): CCS Development in APEC
Economies
Chair: (Korea) Dr. Byungmoo Min,
Principal Research Engineer,
Korea Institute for Energy Research (KIER)
Speech 1: Current Status of CCS R&D in Japan(Japan) Dr. Masato Takagi, Director, Tokyo Branch,
Expert Director, Research Planning Group,
Research Institute of Innovative Technology for the
Earth (RITE)

Speech 2: Low Rank Coal Utilization by HWT(Japan) Mr. Yoshiki Ueno, Senior Engineer,
Technology and Development Department, JGC
Corporation

Speech 2: Overview and Status of CCS
Developments in Canada(Canada) Dr. Frank Mourits, Senior Science &Technology Advisor, Natural Resources Canada(NRCan)Speech 3: Investigation of Clean Methane
Production from Low Rank Coal
(Japan) Mr. Masataka Masuda, Manager, Process
Engineering Team, AATG Process Development
PJ Team, Engineering Department, Osaka Gas
Co., Ltd.

Speech 3: Current Status of CCS Project in Korea(Korea) Dr. Kynwoo Han, Senior Research Engineer,
Research Institute of Industrial Science andTechnology (RIST)

10:20-10:40 Coffee Break

10:40-12:00

10:40-11:00

11:00-11:20

11:20-11:40

Session 4-A (ii): Low Rank Coal Utilization
Technology (ii)
Chair: (Indonesia) Mr. Jeffrey Mulyono, Vice
Chairman,Standing Committee, Indonesia
Chamber of Commerce and Industry (KADIN) /President Director, PT Bhakti Energi Persada
Speech 1: Low Rank Coal Utilization inIndonesia(Indonesia) Mr. Jeffrey Mulyono, Vice Chairman,
Standing Committee, Indonesia Chamber ofCommerce and Industry (KADIN) /President Director, PT Bhakti Energi Persada
Speech2:
Twin
IHI
Gasifier(TIGAR)
Technology for Chemical Feedstock(Japan) Mr. Shuzo Watanabe, General Manager
Gasification & Oxy-Fuel Combustion, Power Plant
Division, IHI Corporation

Session 4-B (ii): CCS Development in APEC
Economies (ii)
Chair: (Canada) Dr.Frank Mourits,
Senior Science & Technology Advisor,
Natural Resources Canada(NRCan)

Speech 3: Future Perspective of Low Lank
Coal Utilization(Japan) Dr. Shunichi Yanai, Director,
Environment Department, New Energy andIndustrial Technology Development Organization(NEDO)

Speech 3: Assessment of the Capture and Storage
Potential of CO2 Co-Produced with Natural Gas inSouth-East Asia
(Australia) Dr. Guy Allinson, Senior Lecturer,
School of Petroleum Engineering,
University of New South Wales (UNSW)

資料5

Speech 1: Toshiba’s Activity in Post Combustion
CO2 Capture Technology(Japan) Mr. Kiyoshi Miyaike, Senior Fellow,
Thermal & Hydro Power Systems & Services Division
Toshiba Corporation Power Systems Company
Speech 2: Current Status of CCS Project inChinese Taipei(Chinese Taipei) Mr. Shoung Ouyang,
Senior Researcher and Chief Project Leader,Green Energy and Environment Labortories,
Industrial Technology Research Institute (ITRI)Speech 4: Interagency Task Force on CCS(US) Mr. Jarad Daniels, Director, Office of Planning& Environmental Analysis, Office of Fossil Energy,
Department of Energy (DOE)

11:40-12:00

12:00-13:00 Lunch

13:00-14:45 Session 5 Panel Discussion : Direction on CO2 Reduction in APEC Region
Moderator: (Japan) Prof Takeo Kikkawa, Graduate School of Commerce and Management,
Doctor of Economics, Hitotsubashi University
Panelist 1 (Australia) Mr. John Karas, Manager, Low Emissions Coal Policy Section, Department of
Resources, Energy and Tourism (DRET)
Panelist 2 (US) Mr. Jarad Daniels, Director, Office of Planning & Environmental Analysis, Office of Fossil Energy,
Department of Energy (DOE)
Panelist 3 (Indonesia) Mr. Jeffrey Mulyono, Vice Chairman, Standing Committee, Indonesia Chamber of Commerceand Industry (KADIN)
Panelist 4 (Canada) Dr. Frank Mourits, Senior Science & Technology Advisor, Natural Resources Canada (NRCan)
Panelist 5 (Japan) Mr. Masamichi Hashiguchi, Director, Coal Division, Natural Resources and Fuel Department,
Agency for Natural Resources and Energy (ANRE), Ministry of Economy, Trade and Industry (METI)
15:00-15:10 Closing Remarks: Mr. Scott Smouse, APEC EGCFE Chair
15:10

Day 2 Adjourns

15:30-18:00 APEC EGCFE Business Meeting (Official Representatives Only)

資料6

October 29, 2010 (Friday)

Day 3

TECHNICAL TOUR
(Authorized Members Only)
8:30 ~ 16:00
EAGLE (Coal Gasification) Pilot Plant, J-POWER

08:30
10:00
12:00
13:00
16:00

Depart from Hilton Fukuoka Sea Hawk by bus
Plant tour
Lunch in the Plant
Dep art from the Plant
A rrival back to Hilton Fukuoka Sea Hawk

INFORMATIONEAGLE (Coal Gasification) PILOT PLANT, J-POWER

Fukuoka-Prefecture
EAGLE Pilot Plant

Hilton Fukuoka Sea Hawk

Kyushu Island

資料7

２． 講演資料

資料8

(1) 開会セッション

資料9

WELCOME AND OPENING REMARKS
Scott M. Smouse, Chair
Expert Group on Clean Fossil Energy
New Developments in Clean Coal and CO2 Reduction Technologies
APEC Clean Fossil Energy Technology and Policy Seminar
Fukuoka, Japan
27 October 2010
Good morning. My name is Scott Smouse, and I chair the APEC Expert Group on Clean
Fossil Energy, which organized this Clean Fossil Energy Technical and Policy Seminar. It isan honor to be with you this morning to open this event. The Expert Group is grateful to theJapanese Ministry of Economy, Trade and Industry (METI), and to our Japanese co-sponsors,
the New Energy and Industrial Technology Development Organization (NEDO), and theJapan Coal Energy Center-Japanese Center for Asia Pacific Coal Flow (JCOAL- JAPAC), forhosting this seminar. I also want to thank our other sponsors, Natural Resources Canada(NRCAN) and the Australian Department of Resources, Energy and Tourism (DRET).
Let me welcome all representatives of governments and companies joining us here in
Fukuoka. This is my second trip to this city – in fact, my first trip to Japan was to Fukuoka inmany years ago for a bilateral cooperation meeting. It’s a pleasure to see so many of myfriends from throughout the region in the audience this morning. Many of you have traveleda long way to participate in this seminar. And I’d particularly like to express our appreciationin advance to the speakers and panelists who will be sharing their knowledge and experience
with us during these 2 days.
The theme of this seminar is “New Developments in Clean Coal and CO2 Reduction
Technologies.” The need to reduce CO2 emissions to address climate change figures very
prominently in high-level discussions in APEC and other international for a. For example,
senior officials from governments met with their counterparts from around the world at theUnited Nations Climate Change Negotiations earlier this month in Tianjin, China, in the leadup to the UN Framework Convention COP-16 meeting, which will start at the end of next
month in Cancun, Mexico. There, they will continue to discuss the intertwined issues of
economic development and prosperity, energy security, and protection of the earth’s
environment.
The dangers posed by increasing concentrations of carbon dioxide in the atmosphere havebeen the motivation for efforts to develop climate change mitigation strategies that can findwidespread support around the globe. Concerns over the risks posed by climate change are
putting pressure on those currently using or considering the use of any fossil fuel-basedenergy system to select an alternative energy source, such as renewable or nuclear energy. At

資料10

the same time, the world economy is still struggling to emerge from a global recession thathas shifted many governments’ focus to economic recovery, which makes addressing otherpressing issues, including climate change, more difficult.
The fact that energy underlies economic development, alleviation of poverty, and a host ofother positive social outcomes makes development of such strategies very complex. Once
one looks to studies that avoid narrow advocacy of a particular technology or a particular fuel,most major analyses argue, if we hope to develop cost-effective solutions to the linked
problems of energy security, environmental protection, and economic development, that weneed to safely produce all energy resources; to use them as efficiently and cleanly as possible;
to prepare to adapt to the impact of likely climatic changes; and to put substantial effort intotransiting to a low-carbon energy economy over the next few decades. Individual actions by a
few nations, focusing on limited portfolios of mitigation technologies, will likely cost much
more and run the risk of serious damage to national economies and to the global economy.
This need for balance brings us back to the subject of this seminar: clean coal and CO2
reduction. The continued support for development and deployment of low-carbon, near-zeroemission, coal-based technologies is a critical part of a sound portfolio of responses to thedangers posed by climate change. This priority has been voiced repeatedly by our leaders andsenior officials in the final declarations and statements at a number of high-level meetings of
APEC and other multilateral fora.
APEC Energy Ministers held their 9th Meeting in Fukui, Japan in June, where they issued a
Declaration on Low Carbon Paths to Energy Security. This Declaration stated that more
efficient use of energy and a cleaner energy supply will simultaneously boost our energy
security, grow our economies, and lower our emissions. It also emphasized clearly that fossil
fuels will continue to play a key role in the APEC energy market, and that cost-effective
technologies for carbon capture and storage (CCS) are essential if the many APEC economies
that still rely on coal and other fossil fuels for a significant portion of their electricity
generation are to significantly reduce their carbon emissions. The Ministers urged redoubling
efforts to develop and deploy clean coal technologies and CCS, and share information onthem through multilateral fora.
Specifically, the EMM-9 Declaration instructs the Energy Working Group (EWG) to extend
and reinforce its analysis of technology options for CCS and its dissemination of bestpractices for applying these technologies to new and existing power plants, working with the
EGCFE and other multilateral fora. It also instructs the EWG and EGCFE to develop an
initiative for deploying advanced clean coal technologies, such as Ultra Super Critical (USC)and Integrated Gasification Combined Cycle (IGCC), to make coal-fired power generation
more efficient and cleaner.

資料11

Also in June, the G8 meeting in Muskoka, Canada, emphasized the role that CCS needs toplay in transitioning to a low-carbon economy and achieving at least a 50% reduction of
global emissions by 2050. In that regard, they welcomed the progress already made on 2008
G8 Hokkaido summit commitments to launch 20 large-scale CCS demonstration projects
globally by 2010 and to achieve the broad deployment of CCS by 2020, in cooperation with
developing countries. The G8 declaration stated that “several of us commit to accelerate the
CCS demonstration projects and set a goal to achieve their full implementation by 2015.”
This pronouncement recognized the findings of a report to the G8 leaders by the International
Energy Agency (IEA), the Carbon Sequestration Leadership Forum (CSLF), and the Global
CCS Institute (GCCSI), which concluded that realizing the Hokkaido recommendation
remains a challenge and will require that governments and industry accelerate the pacetoward achieving this critical goal.
The joint IEA/CSLF/GCCSI report to the G8 also reiterates that, according to the October
2009 IEA CCS Technology Roadmap, around 100 CCS projects will be required globally by
2020, with roughly half of them in developing countries. This illustrates the magnitude of thechallenge, and the need for governments and industry to intensify their efforts to develop
CCS projects to meet the G8 goals.
Over the past 2 years, governments and industry have begun making substantial financial
commitments – in fact, over $26 billion – for large-scale, integrated demonstration CCS
projects and, by 2020, plan to facilitate the launch of between 19 and 43 such projects.

Coal, in particular, faces a significant challenge. Almost everywhere that it is produced andused, coal is under assault at some level, even though it underpins the economic wellbeing ofmany economies around the world. In the IEA’s 2009 World Energy Outlook, fossil fuelsremain the dominant contributor to energy demand growth in the Reference Scenario,
providing some 77% of incremental demand in the period to 2030. Coal has the highest
growth rate among fossil fuels, with its share of global primary energy rising from 27% in2007 to 29% in 2030. Coal demand is projected to grow at 1.9% per year over that period,
from 4.5 to almost 7 Gt of coal equivalent in 2007 by 2030. The OECD’s share of global coaluse is projected to decline from 36% in 2007 to 23% in 2030. China, whose coal demandalmost doubles over that period, accounts for 65% of the increase in global coal demand.
India’s coal demand, starting from a smaller base in 2007, is projected to multiply by 2.4 by2030, and overtake the United States to become the second largest coal user after China.
Globally, more than 75% of incremental coal demand is for power generation.
The capital required to meet projected energy demand through 2030 in the WEO 2009
Reference Scenario is huge, amounting in cumulative terms to $26 trillion (in 2008 dollars),

資料12

averaging $1.1 trillion per year (or 1.4% of global gross domestic product). The power sector
will require 53% of that investment. Over half of all energy investment worldwide will be indeveloping economies, where demand and production are projected to increase fastest.
The IEA’s new Energy Technology Perspectives (ETP 2010), published earlier this year,
looks beyond the 2030 timeframe to 2050, and examines the possibilities that might beoffered by energy technology and policies in a baseline scenario – essentially an
extrapolation of the WEO 2009 Reference Scenario with no new energy and climate policies– compared with a scenario that has the goal of halving global energy-related CO2 emissions
by 2050 (compared to 2005 levels). In the latter scenario, it examines the least-cost means toachieve that goal by deploying currently available and new low-carbon technologies.
ETP 2010 shows that a very substantial investment will be needed in both scenarios to meet
the world’s growing energy needs. Obviously meeting energy demand growth in a way that
supports the 50% by 2050 goal would be more expensive. However, this has a flip side. Theenergy technology revolution holds significant potential for positive returns on investment.
For example, substantial fuel savings would result from efficiency improvements and as
lower fuel demand drives down prices relative to the baseline scenario. ETP 2010 calculates
that the additional $46 trillion investment needed in the “50% by 2050” scenario would yield,
over the period from 2010 to 2050, cumulative fuel savings equal to $112 trillion.
While this looks like a win-win situation – lowering the risk and adverse consequences ofmajor climate change – the IEA report points out that the next decade is critical. If emissions
do not peak by around 2020 and decline steadily thereafter, achieving the needed 50%
reduction by 2050 will become much more costly. In fact, it observes that the opportunity toreach this target may be lost completely. Attempting to regain a 50% reduction path at a later
point in time would require much greater CO2 emission reductions, entailing much more
drastic action on a shorter time scale and at significantly higher cost than may be politically
acceptable.
Looking specifically at fossil fuels in the ETP’s 50% by 2050 scenario, CCS accounts for
19% of the reduction in CO2 emissions relative to the baseline scenario, and power generation
efficiency and fuel switching for 5%. CCS is used to capture 9.4 Gt of CO2 from plants in
power generation (55%), industry (21%), and fuel transformation (24%).
Conclusions from this type of scenario-based, goal-oriented, crystal-ball gazing underline thecrucial importance of advanced coal-based technologies, including high-efficiency power
generation, advanced environmental control technologies for criteria pollutants (SO2, NOx,particulates, mercury), and carbon capture and storage.
As I mentioned earlier, there are efforts underway in a number of countries to build anddemonstrate CCS technologies at scale. This afternoon, you will hear reports on advances in

資料13

implementation of high efficiency, supercritical and ultrasupercritical generation technologies
and in IGCC in the Asia Pacific region. And the focus of tomorrow’s program on CCS in a
number of APEC economies bears witness to the increasing priority being given to thistechnology.
We’ve spoken briefly about global efforts to develop and demonstrate near-zero emission
coal-based technologies. But even with the promise of low-carbon emissions though newtechnologies, issues beyond technology must also be addressed. Some of the early
demonstration projects for CCS, alongside renewable energy projects of all sorts, have run
into considerable opposition from various stakeholders. Opposition to CCS is part of thegeneral public backlash around the world against all sorts of energy projects. While thesevoices must be heard, delays in demonstrating and moving new technologies, such asadvanced coal power and CCS technologies, towards commercial readiness may have serious
consequences given that no single technology can possibly meet the entire world’s or evenone country’s or regions energy needs. Diversity and balance are key.
Where does APEC’s Expert Group on Clean Fossil Energy come into this picture?
The EGCFE has been an active participant in this area. Most of our recent projects havefocused on various technical aspects of coal power generation and best practices for coal
power generation in APEC economies. These reports addressed ways to increase the uptakeof new clean coal technologies, as well as renovation and modernization and efficiency
improvement in existing coal power plants – all which would result in more reliable power
generation, lower emissions of pollutants and CO2, and reduced operations and maintenance(O&M) costs.
The EGCFE has also been actively in CCS technology and including capacity building indeveloping APEC economies that have substantial current and projected growth in coal-fired
power generation. Canada has been leading this multi-phase program, which has developed acomprehensive set of training modules on technical, economic, legal, regulatory, and public
consultation aspects of CCS. We’ve held five capacity building workshops, including two
over the past year in Indonesia and China, in APEC developing economies. We’ve also
published Planning and Cost Assessment Guidelines for Making New Coal-Fired Power
Generation Plants in Developing APEC Economies CO2 Capture Ready. This project
identified a number of issues that potentially impact the development and implementation of
CCS capture-ready plants both globally and within developing APEC economies anddeveloped guidelines for planning and cost assessment related to making new coal-fired
power plants in developing APEC economies capture ready.
And a new project on “Permitting issues related to new coal-based power plants, including
carbon capture and storage, in developing APEC economies” will review the work inprogress around the region and globally on legal, regulatory, and permitting issues and

資料14

frameworks for CCS, identify issues likely to arise if they were to be applied to future CCS
projects in developing APEC economies, and make recommendations for needed capacity
building on permitting CCS projects in these economies.
Finally, we are hoping to bring all the recent EGCFE activities related to CCT and CCS
together in a Workshop on Implementation of CO2 Emission Reduction Technologies andMethods for Fossil Fuel Power Plants during 2011. We are discussing the possibility ofholding this event in cooperation with the IEA, perhaps in conjunction with a related IEA eventin the region.
In closing, the rapid development and deployment of a wide range of low-carbon
technologies, including for fossil energy, is crucial if we are to ensure reliable, affordable,
clean energy for all while protecting our planet. This must be done to lift the impoverishedpeople of the earth to a higher quality of life while resolving the economic woes currently
affecting most nations. Coal-fired generation has changed considerably over the last few
decades and will undoubtedly continue to evolve. Clean coal technologies – developed inpartnership between governments, industry, and academia around the world conducted overthe past 20-30 years – have significantly reduced pollution from coal power generation in thedeveloped countries such as the United States, Japan, and most European countries. Many
leaders in government and industry agree that we must make an even greater change in theway that we use coal today by adopting carbon capture and storage. Use of these technologies,
however, is contingent on overcoming a variety of economic, technical, legal, and public
perception challenges. If coal is to remain a significant contributor to the global energy mix,
these challenges must be overcome. We look forward to hearing from the experts here today
and tomorrow on how they are working to make this a reality.
Thank you.

資料15

The Position of Coalon the New Strategic Energy Plan
October 27, 2010
Hisayoshi Ando
Director General,
Natural Resources and Fuel Department,
Agency for Natural Resources and Energy
Ministry of Economy, Trade and Industry
資料16

Table of Contents
1. The Roles of Coal among Energy Resources in the World
2. Positioning of Coal in the Basic Energy Plan
3. Further Low Carbonization in Coal-Fired Thermal Power
4. Measures for Ensuring Stable Supply of Coal Resources
資料171

1.Role of Coal in World’s Energy Balance
The share of coal accounts for one-quarter of total primary energy supply in the world and its
consumption is expected to achieve a 1.5 fold increases in 2030.
[Primary Energy Demand by Fuel: World]

１.５ times

２７％

２９％
Source: IEA, “World Energy Outlook 2009”[Composition of Primary Energy Consumption in Major Countries (2007)]
0%

10%

20%

40%

50%

60%

70%

66%

China

United States

24%

Japan

22%

24%

35%

18%

United Kingdom

Oil

32.6%

Source:Gas

34%

Nuclear

16%
25%

31.5%

27%

World Total

1.8%
0.7%
23%

39%

26%

Germany

6%

45%

19%

EU

80%
18%

41%

India

Coal

30%

90%

100%

3% 2.1% 10%
0.8%
27%

0.3%
0.3%

9% 0.9% 0.6%
4%
13% 1.2% 0.8%
1%14%
1.5% 6% 0.9%

23%

11% 0.5% 7%

39%

8%
0.4%
0.2% 2%6% 2.2% 10%
0.6%

21%

Hydro
Biomass
資料18

0.8%

Other Renewable

IEA, "World Energy Outlook 2009"& "Energy Balances of OECD Countries (2009 Edition)"2２. The Position of Coal on the New Basic Energy Plan
1.Shift to low-carbon systems in coal-burning power generation
1-1 Further shift to low-carbon systems in coal-fired power generation inJapan
1-2 Shift to low-carbon systems in overseas coal-fired power
generation

2. Measures for ensuring stable supply of coal resources
2-1 Frontier development and closer cooperation with coal-producing
countries
2-2 Effective use of low-quality coal for developing the new and clean energy
sources

資料193

3-1.Promotion of the Low Carbonization of Coal Fired Thermal Power in the world
based on the technical transfer(1)ThermalEfficiency (Gross, LHV)
熱効率（発電端・LHV）
（％）
43

Japan

41

Germany

39
US

37
35

Australia

33

China

31

India

29
27

Japan

GermanyUS

Australia

China

India

25
1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005（Year）
INTERNATIONAL COMPARISON OF FOSSIL POWER GENERATION EFFICIENCY(ECOFYS) (2008)
資料204

3-1.Promotion of the Low Carbonization of Coal Fired Thermal Power in the world
based on the technical transfer(2)Comparative example of coal-fired thermal
power and aged deterioration
Power generation edge thermal efficiency(%, HMV)

Takasago Coal-Fired Power Generation Plant Unit1, Unit2

Efficiency maintainance by proper
operation and management

Decrease in thermal efficiency

Coal-fired power plant of Xs

The Federation of Electric Power Companies of Japan

資料21

5

3-2. Further Promotion of Low Carbonization and Zero Emissions
in Domestic Coal-Fired Thermal Power (1)(1) Development, demonstrations and introduction of highly efficient coal fired thermal power
Efficiency Improvement of
Coal Fired Thermal Power Plants
５４％ＵＰ

３６％ＵＰ

資料22
Source:“Cool Earth 50 – Energy Innovative Technology Plan”

6

3-2. Further Promotion of Low Carbonization and Zero Emissions
in Domestic Coal-Fired Thermal Power (2)Verification of coal-fired power generation including CCS

Development of CCS towards zero emission coal-fired power generation
・ Implement full-swing verification tests of a consistent system for separating, collecting,transporting and storing CO2 emitted in coal-fired power generation, etc, in order to achievealmost zero CO2 emissions eventually by combining highly-efficient coal-fired thermal power
and CCS, and aim at the realization of zero emission coal-fired power generation.

Cool Gen Plan
Osaki Cool Gen Plan
Outline: Large-scale verification test for IGCC/CO2 separation& collection technology
Location: On the site of Osaki Power Plant of Chugoku ElectricPower (Osaki Kamijima-cho in Hiroshima Pref.)Scale: Amount of coal used 1,100 ton/day level (Output power
170,000 kw level)

Osaki
Point

Test run: 2016 to 2019 fiscal year (plan)
Main implementation entity: Osaki CoolGen Corporation

資料23(company invested by Chugoku Electric Power Co., Ltd. and ElectricPower Development Co., Ltd.)7

3-3. Promotion of International Joint Verification Research with Australia
and Other Countries
Development and verification of CCS towards zero emission coal-fired power generation(1) Callide Oxyfuel Project
Joint Australia- Japan verification project where the existing Callide Power Station in Queensland inAustralia is converted into an oxyfuel system which can easily capture CO2 and emitted CO2 iscaptured and stored.
CO2 storagesite

Callide Power Station

Australia

Brisbane

Queensland in Australia (near Brisbane)(2) ZeroGen Project
Project where an IGCC station with a CO2 collection/storage function is constructed. Advanced by
ZeroGen Pty Ltd. in Queensland in Australia.
Commercial IGCC station with CCS. The coal gasification technology adopted in this project wasdeveloped by Japan.

資料24

8

3-4. Promotion of Low Carbonization
by Technology Transfer to Overseas Coal Fired Thermal Power Plants (1)Market size of 10 to 20 trillion yen/year. The capacity of power generation facility is expected to be double by 2030.
Regionally, notable demand expansion in Asia such as India and China.
Demand for highly efficient coal-fired power generation is expected to increase in advanced and emerging countries due to the necessity of global
warming prevention measures.

Russia5.3 trillion yen(52GW → 73GW)

EU-10.5 trillion yen(200GW → 158GW)

Middle East
2.8 trillion yen(5GW → 16GW)

North America

Japan
China

-0.8 trillion yen(44GW → 41GW)

9.8 trillion yen(354GW → 393GW)

193.3 trillion yen(502GW → 1275GW)

ASEAN
22.8 trillion yen(28GW → 119GW)

Africa6.8 trillion yen(41GW → 68GW)South America

S.Korea＋Aus＋NZ

4.5 trillion yen(6GW → 24GW)

2.5 trillion yen(53GW → 63GW)

India
71.5 trillion yen(78GW → 364GW)

Outlook for introduction of coal-fired power generation in the world
The above amounts represent market size expected to newly appear by 2030.
(Estimation based on the assumption of 250 billion yen/GW)
The figures in brackets under each amount represent facility capacity in 2007資料25
andpredicted facility capacity in 2030.

* Created based on IEA World Energy Outlook 2009 reference scenario.

2007 actual2030 outlook(Unit: GW)* A considerable number of old facilities
is expected to be replaced inadvanced countries (North America,
EU, Australia, Japan, etc) but these
are not included in the estimate.

9

3-4. Promotion of Low Carbonization
by Technology Transfer to Overseas Coal Fired Thermal Power Plants (2)1-2. Promotion of Low Carbonization by Technology Transfer to Overseas Coal Fired Thermal
Power Plants(1)Promotion of technology transfer of highly efficient coal fired thermal power technologies according
to the industrial structure of the partner countries(2) Export of systems with operation and management technology (O&M) of coal fired thermal power[Issues]
Incentive grants for CO2 credits, etc.
If Japan world's best standards of coal fired thermal power is applied in China, U.S. and India, it
can contribute to a CO2 reduction of 1,300 million tons
Mt- CO2▲387▲３８７ (mil
（百万㌧）
tons)

2000
(▲776 )(▲387)

＋▲７７６
＋▲776

（百万㌧）
(mil
tons)

＋▲１８４
＋▲184

（百万㌧）
(mil
tons)

About ▲
約 1,300▲１３億㌧
mil tons

1500

1000

1949
1562

2269
1493
ActualResults
572

500
(▲23)
269

246

ActualResults

State of Art
Introduction
Case

0

日本
Japan

ActualResults

State of Art
Introduction
Case
米国
U.S.

ActualResults(▲184 ）)
State of Art
Introduction
Case
388
388

State of Art
Introduction
Case

中国
China
資料26

インド
India

Source: IEA, “World Energy Outlook 2006”10

3-5. Contributions in Other Countries by Japanese Technologies
and Products(Bilateral Offset Mechanism)
New mechanism for overseas contributions
Background○The CDM project currently governed by UN has limits due tobiased target areas and high business risks, etc.
○The Copenhagen Accord (COP15) offers new possibilities toapproaches made by each country independent of UN. U.S.
included a unique mechanism to recognize overseas
contributions by companies, etc into a bill.

New mechanism○ Japan established a new unique mechanism to recognize
GHGs reduction through diffusion of low-carbon
technologies and products which are specialties of Japan,such as highly efficient coal fired thermal power plants andatomic power plants as GHGs reduction by Japan throughpromises between two countries, etc. , which had virtually
not been approved of.

○By strongly backing efforts by private companies,
etc. accelerate the embodiment of the Hatoyama
initiative.

[Example of low-carbon technologies/products of Japan(and predicted GHGs reduction) ]○ Highly efficient coal fired thermal power plants
・ If Japanese technologies were applied to
all the coal fired thermal power plants in U.S.,
China, and India, the amount of CO2 which thewhole of Japan emits would be reduced inthese countries. (Approx. 1.3 billion ton)
○ Atomic power plants
・ The annual CO2 emission reduction effectof a single atomic power plant is approx.
6 million ton.

○Iron and steel
・ Japan maintains the cutting-edge technologies which can almost be usedpractically . If these technologies were applied globally, potential CO2
reduction would be approx. 340 million ton (which is approx. 26% ofemissions in Japan).
○Cement
・ Japan maintains the cutting-edge technologies which can almost be usedpractically . If these technologies were applied globally, potential CO2
reduction would be approx. 180 million ton (which is approx. 14% ofemissions in Japan).

(2) Transfer and diffusion of excellent low-carbon technologies and products of Japan(1) “International promise” between 2 countries, etc.
CO2
Emission
reduction
資料27(3) Appropriately reflected into the achievement ofdomestic targets of Japan

Developing
countries

Japan

Embody the Hatoyama initiative
Support utilizing ODA, JBIC and trade insurance, etc.

11

Ｔｈａｎｋ ｙｏｕ

資料28

The role of coal in a low-carbon future
Bo Diczfalusy
Director, Sustainable Energy Policy and Technology
International Energy Agency

APEC Seminar 2010
Fukuoka, Japan
27-29 October
資料29© OECD/IEA 2010

What role for coal in a low-carbon future?
1. 27% of World Primary Energy Demand issatisfied by coal and 42% of the world’s
electricity is generated from coal.
2. Coal production continues to rise year on year,

primarily to fuel the increasing energy demandsof the developing economies.
 What are the consequences?
 Is it sustainable?
 What can we do about it?
資料30© OECD/IEA 20102

Coal is an important part of global energy supply

Since 2000, coal use has taken a new trajectory.
資料31© OECD/IEA 2010

source: IEA databases3

Where is coal found?

Unlike oil and gas, coal is not concentrated in geopolitically sensitive regions.
source: World Coal Institute© OECD/IEA 2010

資料32

4

Proved coal reserves at end 2009

資料33

source: BP Statistical Review of World Energy 2010
© OECD/IEA 2010

Seaborne flows of traded hard coal, 2008

steam coal
coking coaltotalsources: IEA and VDKI
© OECD/IEA 2010

2008
606.1 Mt
243.2 Mt
849.3 Mt

or 15% of total hard coal production (5 845 Mt)
資料34

資料35

© OECD/IEA 2010

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er A
m
D an
en y
m
B ar
ul k
In ga
do rian
Po esi
rt a
ug
al
C
U
hi
K
ne Ko
se re
Ta a
ip
e
Sp i
ai
Ja n
p
Tu an
rk
R ey
us
si
a

Share of coal-fired plants in power generation, %Share of power generated by coal-fired power
plant
100

90

80

70

60

50

40

30

20

10

0

Coal provides a significant proportion of power
generation in several countries.

7Annual hard coal production to 2008
million tonnes

2,500

2,000

China
USA
OECD Europe

1,500

1,000

500

0
1960

1970

1980

1990

2000

2010

China’s economic stimulus package has resulted ina massive increase in demandfor coal … forcement manufacture, for iron and steel production
and for electricity generation.
資料36

source: IEA Coal Information 2009 (with estimates for 2008)© OECD/IEA 20108

UK coal production 1750 to 2006 andGerman hard coal production 1900 to 2006
300

UK

250

million tonnes

200

150

100

50

Germany

0
1750

1800

1850

1900

1950

2000

2050

Of course, we have seen it all before. But themagnitude ……? No.
資料37

source: Cleaner Coal in China, OECD/IEA 2009
© OECD/IEA 2010

9

The importance of coal in meeting recent growthin energy demand
World's Average Annual Growth Rates in Primary Energy
Demand between 2000 and 2008

Increase in Primary Energy Demand, 2000-08

index: 2000=100

140

5.58%
% = average annual rate of growth

Oil

130

3.05%

120

2.8%
2.52%

110

1.38%
0.68%

100

Coal/peat

Gas
Nuclear
Hydro
Renewables

90
2000 2001 2002 2003 2004 2005 2006 2007 2008

Demand for coal has been growing faster than any
other energy source and is projected to account for
more than a third of incremental global energy
資料38
demand to 2030.
© OECD/IEA 2010

OECD and non-OECD primary energy demand in
the Baseline scenario
25 000Mtoe

20 000
15 000
10 0005 000

2007

Baseline 2015 Baseline 2030 Baseline 2050
OECD

Non-OECD

Primary energy demand in non-OECD countries is
projected to increase much faster than in OECD
countries in the Baseline scenario.
資料39

source: IEA Energy Technology Perspectives 2010
© OECD/IEA 201011

Gt CO 2

Global energy-related CO2 emissions in the Baseline
and BLUE Map scenarios
60
60
50
50

Other

40
40

Buildings
Transport

30
30

Industry

20
20

Other transformation
Power generation

10
10
00
2007
2007

2050

2030
BLUE
Map
Baseline

Global CO2 emissions double in the Baseline, but inthe BLUE Map scenario abatement across all sectors
reduces emissions to half 2005 levels by 2050.
資料40

source: IEA Energy Technology Perspectives 2010
© OECD/IEA 2010

Gt CO2

Key technologies for reducing global CO2 emissions
60
55

Baseline emissions 57 Gt

50
45
40

Power
generation
efficiency
and
Power
generation
efficiency
andEnd-usefuel switching15%
fuelfuelswitchingswitching 5%5%Power generation efficiency andNuclear6%
Nuclear6% 5%fuel switching

35
30
25
20
15

End-usefuelandelectricity
andelectricity
End-useelectricity
End-usefuelandelectricity
End-usefuelfuel
andandelectricity
efficiency
38%
38%
efficiency
38%
efficiency
38%
efficiency
38%
End-usefueland electricity
End-usefuel switchingswitching 15%
15%
End-usefuelefficiency
38%
End-use fuel switching 15%

Renewables
Renewables 17%
17%
BLUE Map emissions 14 Gt

10

CCS 19%502010 2015 2020 2025 2030 2035 2040 2045 2050

A wide range of technologies will be necessary to
reduce energy-related CO2 emissions substantially.
資料41© OECD/IEA 2010

source: IEA Energy Technology Perspectives 2010

CO22
Gt CO

World energy-related CO2 emissions abatement byregion60
55

Baseline emissions 57 Gt

50
45
40
35

China
27%
China
27%
China
27%
India 12%
12%
India
India
12%

30
25
20
15

UnitedStates11%
UnitedStates11%
UnitedStates11%
UnitedStates11%
UnitedUnitedStates11%
UnitedStates
States11%
11%
OECD
Europe7%
OECD
Europe7%
OECD
Europe7%Europe7%
OECD
Europe7%
OECD
Europe7%
Other OECD 10%
Other
OECD
10%
Other
OECD
10%
Other
OECD
10%

Other OME 14%
Other OME 14%BLUE Map emissions 14 Gt

Other Non-OECD 19%

1052010 2015 2020 2025 2030 2035 2040
2040 2045
2045 2050
2050

In the BLUE Map scenario, most of the reductions inenergy-related CO2 emissions are in non-OECD
countries.
資料42© OECD/IEA 2010

source: IEA Energy Technology Perspectives 2010

PWh

Decarbonising the power sector –a new age of electrification?
50
Other
Solar

45

Solar
Wind

40

Wind
Biomass+CCS
Biomass+CCS
Biomass and waste
Biomass and waste
Hydro
Hydro
Nuclear
NuclearNatural gas+CCS
Natural gas+CCS
Natural gas
Natural gas
Oil
Oil
Coal+CCS
Coal+CCS

35
30
25
20
15
10
5

Coal

0
2007

2007 2050
Baseline

Baseline
2050
BLUE
High
Ren
2050
High
Nuclear
2050
BLUE
Map
2050
BLUE Map BLUE
BLUE
High
BLUE
High Ren
2050
Nuclear 2050
2050

A mix of nuclear, renewables and fossil-fuels with CCS
will be needed to decarbonise the electricity sector.
資料43© OECD/IEA 2010

source: IEA Energy Technology Perspectives 2010

Coal remains a key fuel worldwide … even if its
share falls
35%

ETP 2010
Baseline

WEO 2009
Reference30%
historical data
25%

WEO 2009
450 Scenario

20%

ETP 2010
BLUE Map Scenario

15%

10%
1970

1980

1990

2000

2010

2020

2030

2040

2050

Coal technologies are key elements of a sustainable,
least-cost portfolio. 資料44
© OECD/IEA 2010

source: IEA Energy Technology Perspectives 201016

GW installed

Age profile of coal power plants in China

160
140
120
100
80
60
40
20
0

Power plants in China are, in many cases, newer andmore efficient than those in IEA member countries.
資料45© OECD/IEA 2010

source: IEA Clean Coal Centre, CoalPower5 databaseGW installed

Age profile of coal power plants in IEA member
countries

120
100
80
60
40
20
0

Many older power plants in IEA coal-using member
countries will need replacing or upgrading.
資料46© OECD/IEA 2010

source: IEA Clean Coal Centre, CoalPower5 databaseIsogo Thermal Power Station

source: J-Power© OECD/IEA 2010

資料47

19

MtCO2/year Captured

CCS: an ambitious growth pathway

OECD regions must lead in demonstrating CCS, but
the technology must quickly spread to the rest of the
world
資料48
© OECD/IEA 2010

source: IEA CCS Technology Roadmap

20

Conclusions
1. Coal usage is increasing
2. For a low-carbon future, it is essential that weinvest in improving energy efficiency and in
decarbonising the power sector
 Energy efficiency, renewables and nuclear power

3. It means using less coal while, at the sametime, investing in technology development
 Efficiency improvement
 Carbon capture and storage

4. It’s tough, but it’s achievable
5. Coal will remain important to world energy

supply for the foreseeable future.
資料49© OECD/IEA 201021

www.iea.org/techno/etp/index.asp

Thank youbo.diczfalusy@iea.org
資料50© OECD/IEA 2010

U.S. Department of Energy
Carbon Capture and Storage (CCS)
Development Status

Mr. Jarad Daniels
October 27, 2010

資料51

Energy Reduction
Non-Biomass Renewables
NuclearCommercial Biomass
Coal: w/ CCS
Coal: w/o CCS
Natural Gas: w/ CCS
Natural Gas: w/o CCS
Oil: w/ CCS
Oil: w/o CCS

1,400
1,200

EJ/yr

1,000
800

1,200
1,000
800
600

400

400

200

200

0

0

1,600

2020

2040

2060

2080

2100

2000

Energy Reduction
Non-Biomass Renewables
NuclearCommercial Biomass
Coal: w/ CCS
Coal: w/o CCS
Natural Gas: w/ CCS
Natural Gas: w/o CCS
Oil: w/ CCS
Oil: w/o CCS

1,400
1,200
1,000
800

Energy Reduction
Non-Biomass Renewables
NuclearCommercial Biomass
Coal: w/ CCS
Coal: w/o CCS
Natural Gas: w/ CCS
Natural Gas: w/o CCS
Oil: w/ CCS
Oil: w/o CCS

1,400

600

2000

EJ/yr

1,600

IGSM

EJ/yr

1,600

2020

2040

2060

These models show CCS
meeting roughly 1/3 of totalenergy demand by 2100

400
200
0
2020

2040

2060

2080

2100

Primary Energy from the CCSP
Scenarios ( ≈ 450 ppmv CO2)

600

2000

GCAM

2080

Source: PNNL

2100

MERGE

資料52

American Reinvestment and Recovery Act:
Down Payment for CCS Development
Carbon Capture and Storage: $3.4 billion• $1,000 M for FutureGen 2.0• $800 M additional for the Clean Coal Power Initiative
Round III Funding Opportunity Announcement• $885 M for a range of industrial carbon capture andenergy efficiency improvement projects• $635 M for Development of Pilot scale CCS Technologies• $50 M for further geologic site characterization• $20 M for CCS education and training
資料53
3

Major CCS Demonstration Projects
Post-Combustion
IGCC

Basin Electric

Oxy-Combustion

FutureGen

HTC Purenergy Amine Capture
Total: $287M; DOE: $100M• EOR or Saline Storage – 1.0 MTPY
• 120 MWe Slipstream

B&W Oxy-Combustion
DOE: $1.048B• Saline Storage – 1.0 MTPY
• 200 MWe (gross)Industrial (ICCS)

Archer Daniels Midland

HECA
GE Gasifier/Rectisol CO2 Capture
Total:~$2.8B; DOE: $408M• EOR Storage – 2.0 MTPY
• 250 MWe (net)Industrial Power & Ethanol
DOW Alstom Amine
Total$ 208; DOE:$141
Saline, 1 MTPY

NRG
Fluor Econamine FG PlusSM
Total: $334M; DOE: $167M• EOR Storage – 0.4MTPY• 60 MWe Slipstream

AEP

Air Products

Alstom Chilled Ammonia
Total: $668M; DOE: $334M•SalineStorage – 1.5 MTPY
• 235 MWe Slipstream

SMR H2 Production, VPSA
Total$ 431; DOE:$284
EOR, 1 MTPY

Summit TX Clean Energy
Siemens Gasifer/Selexol CO2 capture
Total:~$1.7B; DOE: $450M• EOR Storage – 3.0 MTPY• 270 MWe (net)Southern Company
Leucadia Energy
Methanol, Rectisol
Total$ 436; DOE:$261
EOR, 4.5 MTPY
資料54

Transport Gasifier/Selexol CO2 Capture
Total:~$2.9B; DOE: $270M• EOR Storage – 3.0 MTPY
• 582 MWe (net)FutureGen 2.0
Large-Scale Oxy-Combustion Integrated with CCS•

Repower Unit 4 of Ameren’s
Meredosia, IL power station
with coal-fueled oxycombustion technology•

Utilize existing 202 MWe steam
turbine & plant infrastructure•

Pipeline & Sequester CO2 in
Mt. Simon Saline Formation•

Craft Training and Research,
and Visitor Centers to be Colocated at Injection Site

資料55
5

Carbon Capture and Storage:
Annual R&D Budget($ in Thousands)

CaptureStorage
Advanced Power Systems
Crosscutting Research
Total, CCS and Power Systems

FY2010
Enacted50,000138,000
186,700
29,300404,000

FY2011
Request60,500125,000
175,600
42,750403,850

資料56
6

National Atlas Highlights

Saline Formations
Oil and Gas Fields

North American CO2 Storage Potential(Giga Tons)

Unmineable Coal Seams

Conservative Sink Type
Resource
Saline Formations
Assessment Unmineable Coal
Seams

Low

High

969

3,223

70

97

Oil and Gas Fields

82

83

Hundreds ofYears of
Storage
Potential

資料57

Available for download at http://www.netl.doe.gov/publications/carbon_seq/refshelf.html

7

RCSP Phase III: Development Phase
Large-Scale Geologic Tests
5

Core Sampling
Taken

 Nine large-volume tests
 Injections scheduled 2011/2015

Injection
Well Drilled

3

4
1
9

8

2

6

Partnership

7

Injection
StartedInjection Ongoing
Injection Scheduled 2011/2015
Note: Some locations presented on map may
differ from final injection location

1

Big Sky

2

MGSC

Geologic Province
Triassic Nugget Sandstone /Moxa Arch
Deep Mt. Simon Sandstone

3

MRCSP

St. Peter Sandstone

SalineBell Creek Field

Oil Bearing

Devonian Age Carbonate RockSaline

4
5
6
7
8

PCOR

SECARBSWP

9 WESTCARB

Lower Tuscaloosa Formation
Paluxy Formation
Regional Jurassic & Older
Formations
Central Valley

Type
SalineSalineSalineSalineSaline資料58
8

Accelerating Technology Thru Simulation
Utilize Synergies of Science National Laboratories

National Risk
Assessment Partnership
NRAP

Carbon Capture
Simulation Initiative
CCSI

Identify promisingconcepts

Develop optimal
designs

Quantify technicalrisk in scale up

Accelerate learning during development & deployment
資料59

9

資料60

Non-Technical Issues:Role of CCS in Climate Policy•

A cap-and-trade system would
serve to make CCS costcompetitive for widespreadcommercialization.
GW•

EPA analyses of cap-andtrade legislation clearly show
the importance of CCS in
achieving climate goals while
containing costs.

•

If international offsets or otherkey technologies are notavailable, CCS becomes evenmore important as a cost
containment option.

CCS Deployment under American
Power Act
120
100
80
60
40
20
0
2015

2020

2025

2030

EPA - Base case

2035

2040

2045

2050

EPA - No bonus allowances

資料61
11

Non-Technical Issues:
Regulatory Framework•

CCS projects can proceed under existing laws.

•

EPA is developing requirements tailored for CCS, which will reduce
uncertainty for early projects and help to ensure safe and effective
deployment.

••

Safe Drinking Water Act (SDWA): Standards and requirements for permitting
wells used to inject carbon dioxide (CO2) for geologic sequestration.

•

Clean Air Act (CAA): Standards and requirements for reporting CO2 capture andgeologic sequestration.

•

Resource Conservation and Recovery Act (RCRA): Applicability of RCRA to CO2
streams being sequestered.

•Marine Protection, Research, and Sanctuaries Act (MPRSA): Requirements for
sub-seabed disposal of CO2.

Experience gained from regulating and permitting early CCS
projects will inform the need for an enhanced regulatory framework
for widespread CCS deployment.
資料62
12

President’s CCS Task Force:
Key Findings•

There are no insurmountable technological, legal, institutional, or other barriers
that prevent CCS from playing a role in reducing GHG emissions.

•

Lack of a carbon price is the key barrier to commercial deployment of CCS.

•

Existing Federal programs are being used to deploy 5-10 large-scale integrated
CCS projects to be on-line by 2016. However, early CCS projects facechallenges including the cost and performance of current generation
technology.

•

Federal agencies can use existing authorities and programs to begin
addressing barriers for these (and other) early CCS projects while ensuring
protection of public health and the environment.
– Supporting technology development– Providing legal and regulatory clarity– Supporting regulatory implementation– Addressing long-term liability and stewardship– Developing tools for public engagement and outreach
資料63
13

CCS TF – Findings (cont.)•

R&D can enable commercial deployment of CCS by:– Demonstrating available technology to address integration issues,– Improving the cost and performance of 2nd generation CCS technology.

•

Projects can proceed under existing law, however, regulations need to be
developed and/or finalized and regulators need training and tools.

•

Increased coordination with all stakeholders (both Federal and State) will
enhance government’s ability to assist these projects.

•

Open-ended Federal indemnification should NOT be used to address longterm CO2 storage liability. However, long-term liability and stewardship areimportant issues which require further evaluation.

•

Public engagement and outreach is extremely important for CCS.

•

International collaboration complements domestic efforts on CCS and
資料64
facilitates global deployment.

14

Thank You

資料65
15

2010 APEC Clean Fossil Energy Technical and Policy Seminar
Fukuoka, Japan

Outlook of Coal Demand/Supply andCountermeasures towards CO2 Reductionin APEC Region
October 27, 2010
Atsuo Sagawa
Senior Analyst
Coal Group, Strategy and Industry Research Unit
The Institute of Energy
Economics, Japan
資料66

Contents

1. Trend of Coal Demand/Supply
2. Coal Demand/Supply Outlook
3. Potential to Reduction of CO2 Emission

資料67

2

1. Trend of Coal Demand/Supply

資料68

3

World Coal Consumption
 Coal consumption including brown coal has been rapidly increasing in Asia

since 2003 and amount to 6.8 billion tons in 2009.
 In the past ten years, coal consumption including brown coal in China andIndia increase by 2.5 times and 1.8 times respectively.
Mt

Ratio in 2009

7,000
Mｔ
Others
20.9%

17.7％

6,000
AfricaLatin America/Middle East
14.4％

5,000

Japan
2.4%
South Africa
2.6%
Russia3.0%

4,000
Europe/Former USSR
3,000
North America
2,000

64.3％

Germany
3.3%

China
27.2%

Others27.7%

Japan
Inner Circle
3.2%
South Africa(1999)
3.5%
Russia Germany
5.1%
5.0%
India
India
7.8%

9.2%

1,000

Asia/Pacific

USA
13.5%

0
'81 '83 '85 '87 '89 '91 '93 '95 '97 '99 '01 '03 '05 '07 '09*

Note: * estimatedSource: IEA, “Coal information 2010.

資料69

China
45.2%

Outer Circle(2009 Estimated)

USA
20.7%

1999

2009
Estimated

China1,229.0

3,085.6

USA

934.6

920.8

India

350.2

626.4

Germany

229.6

223.4

Russia

226.2

203.7

South Africa

156.5

180.6

Japan

142.6

164.8

Others1,249.4

1,428.2

World4,518.1

6,833.5

Asia

1,918.4

4,253.8(42.5%)(62.2%)

World Coal Production
 Coal production including brown coal has also been rapidly increasing in

Asia since 2003 with expansion of coal demand.
 Top three of coal producer are China, USA and India which are large

consumer, and Australia and Indonesia which are exporter follow to them.
Mt

Ratio in 2009

7,000

AfricaLatin America/Middle East
15.3％

5,000

South Africa
3.6%
Russia4.3%

4,000
Europe/Former USSR

North America
2,000
1,000

63.2％

Others
24.6%

China
27.6%

Outer Circle
South Africa (2009 Estimated)Indonesia
4.4%

3,000

Mt

Others
16.5%

16.6％

6,000

Australia
5.8%

5.0%

Inner Circle(1999)

Russia5.2%
Indonesia
1.6% Australia
6.5% India
7.2%
India

8.1%

Asia/Pacific

USA
14.3%

USA
22.2%

China
43.0%

1999

2009
EstimatedChina1,238.1

2,971.4

USA

996.1

984.5

India

323.6

560.8

Australia

291.0

399.2

Indonesia

73.8

301.5

Russia

235.2

296.8

South Africa

223.5

247.3

Others

1,103.2

1,141.2

World4,484.5

6,902.8

Asia

1,709.2

3,958.2(38.1%)(57.3%)

0'81 '83 '85 '87 '89 '91 '93 '95 '97 '99 '01 '03 '05 '07 '09*

Note: * estimatedSource: IEA, “Coal information 2010.

資料70

5

World Coal Trade Coal export excluding brown coal has been growing with expansion of coaldemand, while amount of coal export in 2009 has been almost in level-off
due to the global financial/economic crisis since autumn of 2008.
Trend of Coal Export

Coal Export/Production in 2009*
Mt

1,000

50

900

45

3,000

2,971
22.8
0.8%

645

601

561

473

468

426

363

366

346

298

322

255

254

290

400

282

500

520

600

711

35

685

700

686

40

30
25
20

232

259

240

221

213

196

198

188

201

189

185

186

199

195

196

100

196

10

186

200

203

15

202

300

0

Export/Production ratio (%)

Amount of export (Mt)

2,500
800

2,000

1,500

'93

'95

'97

'99

Coking coal
Export/Production ratio (all of coal)
Export/Production ratio (steaming coal)

'01

'03

'05

'07

Amountof Export

919
53.4
5.8%

1,000

526
2.2
0.4%
500

5
0

'91

upper： production
middle：export
lower： ratio of export / puroduction

335
263
247
229
230
67
78.1%
116
87.2% 27.1% 50.8%
262

0

'09*

in
Ch

Steaming coal
Export/Production ratio (coking coal)

a

A
US

d
In

ia
s
Au

l
tra

ia
In

n
do

es

ia
S

th
ou

r ic
Af

a

ia

ss
Ru

資料71

Note: * estimated.

Source: IEA, “Coal information 2010.

6

Main Coal Exporting/Importing Counties
Trend of Coal Exporting and Importing Volume by main country
ExportImport

Mt

Mt
200
Australia

Japan

indonesia

China

250

150

Russia

200

Korea

India

Colombia
150
South
AfricaChineseTaipei100

Germany

USA.
100

UK

Canada50
50

Vietnam

Russia

China

USA

0

0
'91

'93

'95

'97

'99

'01

'03

'05

'07

'09*

'91

'93

'95

'97

'99

'01

'03

'05

'07

'09*

資料72

Note: * estimated.

Source: IEA, “Coal information 2010.

7

Coal Demand/Supply in APEC region
 In APEC region, both of consumption and production have been increasing

with economic growth and amount to more than 70% of world. And coalproduction has been exceeding coal consumption.
 More than 65% of coal consumption is used in power sector.
Mt
6,000

80%
Production
Consumption
Production ratio (APEC / World)
Consumption ratio (APEC / World)

5,000

Coal consumption by sector
Mt

75%

5,000
4,500

4,000

70%

3,000

65%

4,000

Others3,500

Commercial

3,000
Residential
2,500

2,000

60%

1,000

55%

2,000

Generalindustries

1,500

Power

1,000

Iron & steel

500

0

50%
'91

'93

'95

Note: * estimated.

'97

'99

'01

'03

'05

'07

'09*

Source: IEA, “Coal information 2010.

資料73

0'00 '01 '02 '03 '04 '05 '06 '07

82. Coal Demand/Supply Outlook

資料74

9

World Energy Outlook The world energy consumption will increase more than 50% by 2035 in the

Reference Case projection.
 The world would likely depend upon fossil fuels heavily.

Fossil Fuel Ratio: 2007: 88.4%  2035: 85.2%
Coal Ratio:
2007: 28.8%  2035: 26.6%
Btoe

Btoe

20.0
Coal
Oil
Natural Gas
Nuclear
Hydro
Others
Total

15.0

2007
%
28.8
36.9
22.7
6.4
2.4
2.8
100.0

2035
%
26.6
32.0
26.6
6.9
2.5
5.4
100.0

2007 → 2035

7.0

Others
Hydro
NuclearCoal
OilNatural Gas
Nuclear
Hydro
Others
Total

6.0
5.0
4.0

%
141
132
179
163
161
291
152

Oil
Coal

10.0

Natural Gas

3.0

Natural Gas

Oil

5.0

2.0

Nuclear
Others

1.0

Coal
0.0
1971

1980

1990

2000

2010

2020

Source: IEEJ Asia/World Energy Outlook 2009.

2030 35

0.0

資料75

1971

1980

1990

2000

2010

2020

H ydro2030 35

10Energy Outlook of Asia-Pacific Energy demand in the Asia-pacific region with mega-population will increase

fast. Its energy consumption will almost double by 2035 in the Reference
Case reflecting electrification and motorization mainly.
 Coal will continue to be the dominant fuel to supply heat and power.

Fossil Fuel Ratio: 2007: 89.0%  2035: 84.8%
Coal Ratio:
2007: 38.3%  2035: 35.4%
Btoe

10.0
Coal
Oil
Natural Gas
Nuclear
Hydro
Others
Total

8.0

2007
%
38.3
33.9
16.8
6.4
2.0
2.6
100.0

2035
%
35.4
30.0
19.4
7.4
2.0
5.9
100.0

Btoe

Others
Hydro
NuclearCoal
OilNatural Gas
Nuclear
Hydro
Others
Total

3.0
2.5

6.0

140
134
174
176
152
341
152

%

Coal
Oil

2.0

Natural Gas
4.02007 → 2035

3.5

Natural Gas

1.5

Oil

1.0
2.0

Coal

Nuclear
Others
Hydro

0.5

0.0

0.0
1971

1980

1990

2000

2010

2020

Source: IEEJ Asia/World Energy Outlook 2009.

2030 35

資料76

1971

1980

1990

2000

2010

2020

2030 35

11

Power Generation Mix by Fuel: World Coal remains the dominant fuel for power generation.
 The CO2 emissions by coal-fired power stations share 30% of the global

emissions. It is projected to increase from 8.2 Gt-CO2 to 12.6 Gt-CO2
between 2007 and 2035. Effective use of coal with CCT is expected to play
an important role to counter the global warming.
TWh

TWh

40.0
Coal
Oil
Natural Gas
Nuclear
Hydro
Others
Total

35.0
30.0
25.0

2007
%
41.7
5.6
20.8
13.8
15.6
2.5
100.0

2035
%
39.8
3.0
26.0
11.8
13.1
6.4
100.0

2007 → 2035

16.0

Coal
Oil
Natural Gas
Nuclear
Hydro
OthersTotal

14.0

Others
Hydro
Nuclear

12.0
10.0
8.0

20.0
15.0

Natural Gas

6.0

10.0

Oil

4.0

5.0

%
183
104
239
163
160
484
191

Natural Gas

Hydro
N uclear
O thers
O il

2.0

Coal

0.0

0.0
1971

1980

1990

2000

2010

2020

2030 35

Coal

1971

1980

1990

2000

2010

2020

2030 35

資料77

Source: IEEJ Asia/World Energy Outlook 2009.

12

Power Generation Mix by Fuel: Asia-Pacific In the Asia-Pacific region, coal is a dominant fuel for power generation, andits share will continue to be high (or more than 50%) in the coming decades.
 The CO2 emissions by coal-fired power stations share 38% of the global

emissions. It is projected to increase from 5.7 Gt-CO2 to 8.7 Gt-CO2
between 2007 and 2035.
TWh

TWh

22.0

Coal
Oil
Natural Gas
Nuclear
Hydro
Others
Total

20.0
18.0
16.0
14.0
12.0

2007 2035
%
%
53.1
51.5
3.9
2.0
16.0
18.3
13.0
12.6
12.2
10.1
1.8
5.5
100.0 100.0

12.0

Coal
Oil
Natural Gas
Nuclear
Hydro
Others
Total

10.0

Others
Hydro
Nuclear2007 → 2035

8.0

%
177
96
208
176
151
539
182

Coal

6.0

10.0
8.0
6.0
4.0

Natural Gas
Oil

4.0

Coal

2.0

Natural Gas
Hydro

2.0

Others
Oil

0.0

0.0
1971

1980

1990

2000

2010

2020

2030 35

1971

1980

1990

2000

2010

Nuclear2020

2030 35

資料78

Source: IEEJ Asia/World Energy Outlook 2009.

13

Power Generation Mix by Fuel: World/Asia-Pacific Coal-fired power plant is indispensable power supply option in both world

and Asia with its economic advantages and the stable availability of its input
fuel.
World
60

Asia Pacific

%

60

%
Coal-fired

50

50

Coal-fired

40%

40

26%

30
20

13%

10

NuclearOil-fired
Other Renewables

0
1980

40
30

Gas-fired

Hydro

1971

51%

1990

2007

2010

2020

Source: IEEJ Asia/World Energy Outlook 2009.

2030

12%
6.5
3.0
%
%

2035資料7920

18%

Gas-fired

Nuclear 13%
10

Hydro

10%
5.5%
2.0%

Oil-fired
Other Renewables

0
1971

1980

1990

2007

2010

2020

2030

2035

14

Coal Demand by Region : World
 90% of global coal demand increase is derived from Asia, and the share of

Asia in total coal demand eventually expands to 67%.
 35% of the increase in global CO2 emissions from 2007 to 2035 is from coal

combustion in Asian region; In order to address global warming problem,
environmentally compatible coal use is quite important agenda in Asia.
5000

Mtoe

Increase from 2007 to 2035

1174
4000

90%
88

3000
Asia

7%

-105

-8%

N.America Europe

147

11%
Other

6%
17%

2000

18%

1000

58%

0
1971

1.3 bil. toe

8%

Other

10%

Europe15%

N.America

67%

2007
3.2 billion toe(4.6 billion tce)↓2035
4.5 billion toe(6.4 billion tce*)
1.4-fold increase(1.8 billion tce inc.)

Asia*Tons of coal equivalent
1980

1990

Source: IEEJ Asia/World Energy Outlook 2009.

2007

2020
資料80

2030 2035

15

Coal Demand by Region : Asia
 Coal will be consumed in the power sector in order to meet growing

electricity requirements, particularly in China and India, both of which haveabundant availability of domestic reserves.
3500
3000

Mtoe
AAGR China India Japan Korea Taiwan Singapore
5.4% 5.9% 2.5% 5.4% 9.2% 3.9%
1980-2007
2007-2035
1.3% 3.4% -0.6% 1.2% 1.0%
Indonesia Malaysia Philippines Thailand Vietnam Other Asia

2500
2000
1500
1000

22.1% 22.1% 11.1% 13.5%
3.9% 4.6% 5.6% 4.7%

China
Japan
Taiwan
Malaysia
ThailandSingapore
Other Asia

India
Korea
Indonesia
Philippines
VietnamHong Kong

5.6% -0.6%
6.3% 3.5%

3%

Japan
India

6%

20%

13%
61%

China

2007
1.8 billion toe(2.6 billion tce)↓2035
3.0 billion toe(4.3 billion tce)
1.7-fold increase(1.7 bil. tce inc.)

70%

500

Source: IEEJ Asia/World Energy Outlook 2009.

0
1971

1980

1990

Source: IEEJ Asia/World Energy Outlook 2009.

2007

資料81

2020

2030 2035

16

3. Potential to Reduction of CO2 Emission

資料82

17

Reduction of Emissions by Advanced Technologies
 Introducing innovative technologies proactively, energy consumption andCO2 emissions could be reduced substantially.
Btoetoe
BillionPrimary Energy DemandPrimary Energy Demand

18.0

45.0

15.727
Reference Case

14.572
11.07810.493
7.993

9.0

14.02528.8
30.5

12.673
Advanced
Technology
Case

38.9

33.9

35.0

18.4

30.8

Advanced
Technology
27.1 Case

25.0

6.549

29.3

21.2

15.0

6.0
1980

41.5

■ Developed countries■ Developing countries Reference Case

13.52612.0

CO2 Emissions

Gt-CO2

16.87715.0

CO2 Emissions

1990

2000

2007

2020

Source: IEEJ Asia/World Energy Outlook 2009.

2030 2035資料83

1980

1990

2000 20072020

20302035

18

Advanced Technology Scenario
In the advanced technology scenario, the world will take countermeasures against global
warming proactively such as adoption of best available technologies and systems andimplementation of intensive R&D of innovative technologies.
National Policy

Promotion of R&D, International Cooperation

Carbon tax, Emissions Trading, RPS, Subsidization, Encouragement of Investment for R&D, International
FIT, Efficiency Standard, Automobile Fuel Efficiency Cooperation on Energy Efficient Technology, Support
on Establishment of Efficiency Standard
Standard, Low Carbon Fuel Standard, Energy
Efficiency Labeling, National Target, etc.

【Demand Side Technology】■ Industry【Supply Side Technology】■ Renewable
Best available technology on industrial process
More expansion of Wind, PV, CSP, Biomass
such as steel making, cement, paper, oil refinery
power generation, Bio-fueletc. become internationally penetrated■ Nuclear■ Transport
Acceleration of more nuclear power plant,
Clean energy vehicles (high fuel efficient vehicle,
Enhancement of operating ratio
Hybrid vehicle, Plug-in hybrid vehicle, Electric■ High Efficient Fossil-fired Power Plant
vehicle, Fuel cell vehicle) globally expand.
More expansion of Coal-fired power plant■ Building(USC, IGCC, IGFC), Natural gas MACC
Efficient electric appliance (Refrigerator, TV etc.),■ CCS
High efficient water-heating system (heat-pump
Introduction in power generation (coal-fired,etc.), Efficient air conditioning system, Efficient
gas-fired) and industrial sector
lighting, Strengthening heating insulation
資料84
19

Power Generation Efficiency of Coal-fired Power Plant
 In Advanced Technology Scenario, additional 1.0 Gt-CO2 will be reduced

due to the enhancement of power generation efficiency compared with
Reference Scenario.
Efficiency of Coal-fired
Power Plant (World)

Power Generation Efficiency of Coal-fired Power Plant *(Reference)

45
40

Power Generation Efficiency、％

35

39

OECD
36

36

World
30
28

39

42
41
40

36
32

Non-OECD

25
1990

40

38

34

33

41

2007
34 ％
↓
2035
Reference A-Tech.
41 ％
45 %
(7points up) (11points up)

2007

Advanced Coal-fired Plant【Breakdown of coal-fired power plantin 2035(World)】
Reference：- SC:70%, - USC/ＩＧＣＣ: 30%
A-Tech.：- SC:10%, - A-USC/ＩＧＣＣ/IGFC: 90%

2020

Source: IEEJ Asia/World Energy Outlook 2009.

2030資料85

2035

70
65

Power
Generation Efficiency (%)
発電効率(%)

60
55
50
45
40
35
Conventional
USC
石炭火力 超々臨界
Coal
A-USC
(現状)

IGCC

IGFC

20

CO2 Capture & Storage (CCS) Cumulative captured and stored CO2 from 2020 to 2035 amounts to 14 Gt-

CO2.Theoretical potential of CCS in geological structure is estimated to 10
trillion ton, and that of depleted gas field, oil field and coal field, 1 trillion ton,which is sufficient to accommodate the captured CO2 in Advanced
Technology Scenario.
3

Gt-CO2 CCS will be introduced after 2020 in coal-fired,gas-fired power generation and industrial sector.
2

1

2.6
0.4

Industry In industrial sector, 10% of its total emissions will

be captured and stored by 2035.

0.0
0.1
0.1

0.4
0.1
0.3

2020

2025

0

Source: IEEJ Asia/World Energy Outlook 2009.

1.0
0.2

2.2

Power
Generation

0.8
2030

資料86

2035
21

CO2 Mitigation by Technology : World Multiple technological options, such as energy saving, enhancement of

power generation efficiency, renewables, nuclear, fuel-switching and CCS
together greatly contribute to massive CO2 mitigation.
45

Gt-CO2

40

World CO2 emissions in
Advanced Technology Scenario
will peak out in 2026

415
Energy Saving

Energy Saving (46%)

46%

Bio-fuel (4%)
PV, Wind etc. (6%)
Nuclear (10%)
Fuel Switching (12%)
CCS (21%)

Fuel Switching

Reference
Reference

35
30

288
Tech.
Adv.
A-Tech

CCS
21%

293

25

Gt

▲123Gt

20
1990

32%

2007

2020

Source: IEEJ Asia/World Energy Outlook 2009.

2035

資料87

(▲30%)

Energy Saving
Bio-fuel
PV, Wind etc.
Nuclear
Fuel Switching
CCS
Total

6
0
1
1
1
3
12

Share
46
4
6
10
12
21
100

22

CO2 Mitigation by Technology : Asia
 Aggressive development and deployment of advanced technology in Asia

enable to considerably reduce CO2 emissions.
20

Gt-CO2

191

Energy Saving

Energy Saving (53%)

12

60%

Fuel Switching

Reference
Reference

16

53%

IncludingHigh-efficiency
Coal-fired Power
plant

107

123

Bio-fuel (2%)
PV, Wind etc. (7%)
Nuclear (10%)
Fuel Switching (12%)
CCS (16%)

31%

CCS
16%

Tech.
Adv.
A-Tech8

4
1990

Asian CO2 emissions in
Advanced Technology Scenario
will peak out in 2030.

2007

2020

2035

▲68Gt

(▲36%)

Energy Saving
Bio-fuel
PV, Wind etc.
Nuclear
Fuel Switching
CCS
Total

Gt
3.6
0.1
0.5
0.7
0.8
1.1
6.8

Share
53
2
7
10
12
16
100

資料88

Source: IEEJ Asia/World Energy Outlook 2009.

23

CO2 Emissions in APEC Region
 In reference scenario, CO2 emission will increase by 7.2 GT to 23.8GT in

2035 and CO2 emission of the coal origin will be about half of amount of
CO2 emission.
 In advanced technology scenario, CO2 emission will only increase by 1.2

GT to 17.7 GT in 2035.
 CO2 emission of the coal origin will be much decrease.

Reference

Advanced Technology

Gt-CO2

Gt-CO2

25

25

18%

20
14%

20
14%

Natural Gas

15

Natural Gas

20%

Oil

32%

53%

Coal

48%

'07

'20

15

30%
Oil

10

32%

10

32%
52%

5
53%

5

Coal

0

0
'71

'80

'90

'00

'07

'20

Note：Russia and Peru are excluded.
Source: IEEJ Asia/World Energy Outlook 2009.

'30

'35

'71

'80

'90

'00

'30

'35

資料89

24

Reduction of CO2 Emission of the Coal Origin by
Advanced Technologies
 CO2 emission of the coal origin will be greatly reduced by the introductionand expansion of advanced technologies (high efficiency technologies and
CCS).
World

APEC Region
Gt-CO2

Gt-CO220

20
18

Reference Case

15

15

Reference Case

12
11

10

10

12

9
8

Advanced Technology Case
5

5

0

0

'71

'80

'90

'00

'07

Note：Russia and Peru are excluded.
Source: IEEJ Asia/World Energy Outlook 2009.

'20

'30

'35

Advanced Technology Case

'71

'80

'90

'00

'07

'20

'30

'35

資料90

25

CO2 Emission of Coal origin in APEC Region
 In reference case, CO2 emission of China will steadily increase driven bycoal consumption and CO2 emission of USA will be stable. The shareaccounting 70% together in APEC region.
 In advanced technologies scenario, CO2 emission of China will decrease by

2.4 GT (34%down) in 2035, compared with reference scenario.
Reference Case

Gt-CO2

Gt-CO2

14

Advanced Technology Case

14
Korea

12

Japan

10

11%

17%
Other

12
10

21%

8
25%

2

Other

6
57%

China

4

Korea

11%

8

USA

6

Japan

25%

19%

USA

21%

4
2

56%

0

56%

55%

China

0
'71

'80

'90

'00

'07

'20

Note：Russia and Peru are excluded.
Source: IEEJ Asia/World Energy Outlook 2009.

'30

'35

'71

'80

'90

'00

'07

'20

'30

'35

資料91

26

Summary and Conclusion
 Fossil fuel consumption will continue to increase in coming decades.
 Coal will remain the major energy source despite its high environmental

burden, because of its price advantages and superior supply stability.
Coal in the APEC region is forecast to bear a high share in the energy mix of2035; 36% for the Reference Scenario and 32% for the Advanced Technology
Scenario.
 The following countermeasures should be required.
IssuesCountermeasures
High Efficiency Technologies-- Deployment of existing superior
technologies (SC and USC)-- R&D of higher efficiency technologies

CO2 Emissions

CCS
Penetration of existing Clean Coal
Technologies

Air and Environmental Pollution
Stable Supply
for Expanding Demand

資料92

High Efficiency Technologies
Use of low-rank coals
27

Thank you very much for your kind attention !

資料93

28

（2）セッション１A

資料94

Coal in Canada
Kevin Stone, Natural Resources Canada
Presented by Dr. Frank Mourits, Natural Resources Canada

APEC Clean Fossil Energy
Technical and Policy Seminar 2010
Fukuoka, Japan, 26-28 October, 2010
資料95

Outline

Canada’s coal sector profileThe role of coal in CanadaCanadian coal reserves and resources

Coal consumption, production, imports and exports

Coal demand and supply forecastGovernment policies



Summary

資料96

Canada’s Natural Resources – Now and for the Future2

Coal Sector Profile

Canada is a mid-sized coal producing country

Annual production about 70 Mt (40% coking and 60% thermal)

Ranks 13th among global coal-producing countries

22 producing coal mines (June 2010)

20 open-pit and 2 underground mines

19 coal-fired power generation plants (June 2010)



A work force in excess of 5000 people

The coal sector is serviced by coal-transporting railways, ports,
equipment suppliers, exploration companies and engineering
firms
資料97

Canada’s Natural Resources – Now and for the Future3

Mines, Ports and Railroads

資料98

Canada’s Natural Resources – Now and for the Future

4Role of Coal in CanadaCoal accounts for 9% of Canada’s primary energy supply

Oil 37%; Gas 40%; Hydro & Nuclear 10%; NGL 4% (2008)

Canada consumes about 60 Mt of coal per year
 90% is used in coal-fired electricity generation
 7% is used by iron and steel industry
 3% is used by various industries

Coal-fired power generation provides about 15% ofCanada’s electricity supply
Domestic production supplies about 2/3 of the total coal use
while 1/3 is supplied by imports
Canada exports over 40% of its coal production
 28.8 Mt in 2009 - 21.4 Mt coking and 7.3 Mt steam

Coal is No.1 commodity carried by rail and handled by ports
資料99

Canada’s Natural Resources – Now and for the Future5Reserves and Resources

Proven resources in place: 8.7 billion tonnes - enoughfor over 100 years at current consumption levels
Proved recoverable reserves, 6.6 billion tonnes- 3.5 billion tonnes of bituminous- 0.9 billion tonnes of sub-bituminous-

2.2 billion tonnes of lignite

Additional resources in place: 192 billion tonnes

-92 billion tonnes of bituminous
49 billion tonnes of sub-bituminous-

42 billion tonnes of lignite

Recoverable resources: 120 billion tonnes
資料100

Canada’s Natural Resources – Now and for the Future

6

Canadian Coal Consumption
70
63
60

62

62

59

62
58

60

2004

2005

58

61

58

56

million tonnes

50

40

30

20

10

1999

Source: Statistics Canada, NRCan

2000

2001

2002

2003

Annual Coal Consumption
資料101

Canada’s Natural Resources – Now and for the Future

2006

2007

2008

2009

Used for Coal-fired Generation

7

Canadian Coal Production
Canadian Coal Production, 1999-2009

80
70

million tonnes

60

Metallurgical

50
40
30

Steam

20
10
0

1999

2000

Source: Statistics Canada, NRCan

2001

2002

2003

2004

Steam

2005

2006

2007

2008

2009

Metallurgical

資料102

Canada’s Natural Resources – Now and for the Future8

Canadian Coal Trade
Exports and Imports

40
35

million tonnes

30
25
20
15
10
5

Exports

20
09

20
08

20
07

20
06

20
05

20
04

20
03

20
02

20
01

20
00

19
99

19
98

19
97

0

Im ports

Source: Statistics Canada, NRCan
資料103

Canada’s Natural Resources – Now and for the Future9

Canadian Demand Forecast
70
58.4

55

55
48

50

48

40
30
20

Actual10

Annual Coal Consumption

20
15

20
14

20
10

20
09

0

20
08

million tonnes

60

Used for Coal-Fired Electricity Generation

資料104

Canada’s Natural Resources – Now and for the Future10

Canadian Supply Forecast
90
80

million tonnes

70
Coking Coal

60
50
40
30

Thermal Coal

20
10
0
2010

2011

2012

2013

資料105

Canada’s Natural Resources – Now and for the Future

2014

2015

11

Government Responsibilities


Canada’s Constitution
 Mineral resources are provincially owned
 Mineral resources offshore and North of 60º are federally owned

Provincial responsibilities
 Mining regulations, permits, operations, reclamation, royalty regime,
safety, labour Shared with federal government: health, environmental protectionFederal responsibilities
 International affairs, trade, investment, fiscal and monetary policy,
science and technology and aboriginal affairs
資料106

Canada’s Natural Resources – Now and for the Future12Federal Minerals and Metals PolicyPromotes partnerships for sustainable miningAffirms provincial jurisdiction and defines federal
responsibilities

Commits to partnerships with stakeholders on environment,science and technology and international tradeEnsures the competitiveness of Canada’s mineral industry
 Fosters competitive environment and attracts investment

Promotes products, markets and stewardship Focus on safe use principle, life-cycle management, sciencebased management of substancePromotes aboriginal involvement in mining activities
資料107

Canada’s Natural Resources – Now and for the Future

13

Environmental Policies
Two federal acts and provincial laws ensure protection of theenvironment in mining operations and new mine projects
 Canadian Environmental Protection Act applies toexisting operations

 Producers must comply with all laws and regulations
 Operations must minimize negative environmental effects
 Producers must reclaim and rehabilitate the mined site and be
certified by provincial authority
 Canadian Environmental Assessment Act focuses on

new projects

 Proponents of new projects must conduct environmental impact
assessment
 Assessed and approved by provincial and federal agencies
資料108

Canada’s Natural Resources – Now and for the Future14

SummaryCoal is an abundant and widely distributed resource in Canada.
Coal is affordable and readily available. The current proven coalreserves could support over 100 years of productionWith sustainable mining practices and the implementation of lowemission clean coal technology at thermal power stations, coal
will continue to play an important role in Canada’s energy supplyCanada has a mature coal industry with an experienced work
force



Coal will have the highest annual growth rate among fossil fuels
to 2030 (IEA). Global demand for coal will require more coalsupply from Canada, and Canada will continue to be a key
supplier of coking coal for global markets
資料109

Canada’s Natural Resources – Now and for the Future

15

Further Information
The Minerals and Metals Policy of the Government of Canada
www.nrcan-rncan.gc.ca/mms-smm/poli-poli/gov-gov-eng.htm
Canadian Minerals Yearbook - Coalwww.nrcan-rncan.gc.ca/mms-smm/busi-indu/cmy-amc/com-eng
Contact
Kevin Stone
Senior Commodity Analyst
Natural Resources Canada
kevin.stone@nrcan-rncan.gc.ca

Thank You!
資料110

Canada’s Natural Resources – Now and for the Future

16

Philippine Coal Policy
By:
Alicia N. Reyes
Director

APEC Clean Fossil Energy Technical and Policy Seminar
Fukuoka, Japan
Oct. 27-29, 2010

PHILIPPINE DEPARTMENT OF ENERGY
資料111

PRESENTATION OUTLINE
 Legal Framework
 Coal Industry Update Clean Coal Initiatives
 Conclusion

資料112

Presidential Decree No. 972
Coal Development Act of 1976
(as amended by PD 1174)
Promotes the accelerated exploration,
exploitation, production and utilization of coal.

development,

Introduced the coal operating contract system andestablished the appropriate guidelines for coal operations in
the Philippines.
The government retains ownership of Philippine coalresource while the operator, through the contract system, isassigned the right to explore, develop, exploit and market thecoal based on some pre-agreed conditions for a specificperiod of time.
資料113

HIGHLIGHTS OF THE CONTRACT
 Contract Term
Exploration:

Development/Production :2 years initial + 2 years extension
10-20 years + series of 3 years extension not toexceed 12 years

 Cost Recovery:

90% of gross income

 Taxes:

exempted from national taxes except income tax

 Profit Share:Government : 30% of net proceeds
Contractor : 70% of net proceeds

 Tax Exemption:

for imported equipment, materials, spare partsand materials

資料114

HISTORY OF PHILIPPINE ENERGYCONTRACTING ROUND (PECR)PECR is a mechanism whereby the government bids out areas with potential
indigenous energy resources for exploration and possible development andproduction. Proposals are solicited from interested parties and evaluated based on
established criteria to determine the qualifications of the bidder. Negotiations
may follow for the details of the contract with the winning bidder.
Scheme started with the Petroleum Contracting Round undertaken with theassistance of Norway in 2003
Geothermal Contracting Round followed on March 11, 2004
PECR for petroleum, COAL and geothermal prospects followed on August 31,
2005
資料115

2009 Philippine Energy
Contracting Round(PECR)
 The 2009 PECR awarded
sixteen (16) Coal Operating
Contracts with total financial
commitments for two (2) years
of US$ 1.8 million

資料116

Department Circular No. DC 2010-03-0005“Providing Additional Guidelines for a Transparent and Competitive System ofAwarding Service/Operating Contracts for Coal and Petroleum Prospective Areas
Amending for this Purpose DC 2006-12-0014.”•Circular provided Guidelines for Public Contracting by Publication•Circular provided specific guidelines for Direct Negotiation:
1.
2.
3.

Frontier areas – privately identified coal and petroleum frontier areas withno available technical data maybe allowed to be offered through negotiatedcontracts.
When no proposal is received during the conduct of PECR or no one
among the applicants was able to meet the minimum requirements after theevaluation.
When no proposal other than the proposal by the qualified nominee isreceived after the publication.
資料117

Coal Industry Update

資料118

2009 Power Situationer
Plant Type

Installed Capacity

Percent Share

Installed

Dependable

Coal

4,277

3,813

27.40

28.63

Oil based

3,193

2,528

20.46

18.98

Natural gas

2,831

2,700

18.14

20.27

Gerothermal

1,953

1,321

12.51

9.92

Hydro

3,291

2,914

21.09

21.88

Wind

33

33

0.21

0.25

Solar

1

1

0.01

0.01

Biomass

30

10

0.19

0.07

資料119

Installed

Dependable

HISTORICAL COAL CONSUMPTION(Years 1977 – 2009)
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 1987 1989 1991 1993 1995 1997 1999 2001 2003 2005 2007

Power Generation

資料120

CementIndustrial/Direct

2009 COAL CONSUMPTION
5.96%
18.79%
75.24%

POWER

9,204,253.96 MT

CEMENT

2,266,903.22

IND'L/DIRECT PROCESS
Total

資料121

571,679.29
12,063,778.81 MT

2009 COAL RESERVESQUEZON
Resource Potential - 2.00
In-situ Reserves- 0.09By Region in Million MT

MINDORO
Resource Potential - 100.00
In-situ Reserves- 1.44BATAN-POLILLOCATANDUANES
Resource Potential - 17.00
In-situ Reserves- 6.07

SEMIRARA
Resource Potential - 570.00
In-situ Reserves- 141.78

MASBATE
Resource Potential - 2.50
In-situ Reserves- 0.08

NEGROS
Resource Potential - 4.50
In-situ Reserves- 2.01SAMAR
Resource Potential - 27.00
In-situ Reserves - 8.59

BUKIDNON
Resource Potential - 50.00

CEBU
Resource Potential - 165.00
In-situ Reserves - 11.67

ZAMBOANGAResource Potential - 45.00
In-situ Reserves- 38.04

SURIGAO
Resource Potential - 209.00
In-situ Reserves- 70.00MAGUINDANAO
Resource Potential - 108.00
SULTAN KUDARATResource Potential - 300.30
SOUTH COTABATO
Resource Potential - 230.40
In-situ Reserves- 79.17CAGAYAN VALLEY
Resource Potential - 336.00
In-situ Reserves - 82.57

DAVAO
Resource Potential - 100.00
In-situ Reserves - 0.21
資料122

SARANGANIResource Potential - 120.00

2009 COAL PRODUCTION(43% of demand)

0.59%
0.46%

2.34%

1.99%

0.97%
93.64%SEMIRARA ISLAND, ANTIQUESURIGAOBATAN ISLAND, ALBAYZAMBOANGA SIBUGAY
CEBU
SSCM

4,846,866.00 MT
121,254.49
50,456.18
30,741.61
23,927.37
102,966.76

資料123

Total

5,176,212.41 MT

2009 COAL IMPORTATION
1.78%

7.40%

90.82%INDONESIACHINA
VIETNAM
Total

6,381,423.37 MT
520,000.00
125,294.79
資料124

7,026,718.16 MT

2009 COAL
EXPORT

16,499.98 MT

Semirara Mining Corp
– 2.3 MMMT or 50% of
production.
Export is allowed only
after ensuring applicable
local demand isaddressed.

547,506.44 MT

29,044.53 MT

844,651.91 MT

54,419.05 MT

769,563.35 MT

資料125

SUAL I & II
(2 x 647 MW)
TEAM Energy

COAL FIRED
POWER
PLANTSMASINLOC I & II
(2 x 300 MW)
AES Transpower Pte
Ltd.

CALACA 1 & 2(2 x 300 MW)
Calaca Holdco Inc.

QUEZON POWER(511 MW)
Quezon Power Phils.

PAGBILAO UNIT 1 & 2(2 x 364 MW)
TEAM Energy

Toledo Power Plant(88.8 MW)
Global Power
Cebu TPP 1 & 2(52.50 & 56.8 MWs)
Salcon Phils.

資料126

Mindanao Coal-firedPower(232 MW)STEAG

CEMENT & INDUSTRIAL COAL END-USERS

資料127

CLEAN COAL POLICY

資料128

The Philippine Coal Contract System
Presidential Decree (PD) 972, otherwise known as the CoalDevelopment Act of the Philippines, as amended in 1977 by PD
1174, governs coal operations in the country.
Section 9 (d) The Contractor shall operate the area on behalf of
the Government in accordance with good coal mining practices
using modern methods appropriate for the geological conditionsof the area to enable maximum economic production of coal,
avoiding hazards to life, health and property, avoiding pollutionof air, land and waters, and pursuant to an efficient andeconomic program of operation;.

資料129

GEOTHERMAL 2

Philippine Environmental Policy Act of1997 (P.D. No. 1151)
Requires the government and all power plant/mining
operators and industrial end-users to undertake detailed
environmental impact assessments of their operational
activities. It requires provision of remedial measures toaddress these impacts particularly combustion/ greenhousegas emissions associated with coal utilization.

資料130

GEOTHERMAL 2

Philippine Environment Code (P. D. No. 1152)
An act providing detailed prescriptions on the management of air quality, water quality,
land use, natural resources, mineral, energy and waste disposal system.
Section 38 b of the code enjoined all power plant operators and industrial end-users aliketo provide pollution control devices to ensure the health and well being of the surrounding
community.
Section 56 of the code, likewise, provides tax exemptions for pollution control equipment,
spare parts, devices and accessories and tax credits for the purchase of domestic pollution
control technologies and expenses incurred in research on such technologies bycoal-fired power plant operators, industrial end users and mine contractors who will installand utilize pollution control in their facilities
Section 57 provides technical assistance/foreign grants for study, design and constructionof environmental facilities.
資料131

GEOTHERMAL 2

DENR Administrative Order No. 14,
Series of 1993
Section 60 a (2) Requires that sulfur content of fossil fuelfor stationary sources, i.e. power and industrial plants,
should not exceed 1% else install appropriate control
equipment.

資料132

GEOTHERMAL 2

Clean Air Act of 1999
(R.A. No. 8749)
Section 19 Article 2 of the Act, requires all coal-fired
power plant operators and coal industrial end-users tofind ways and means to mitigate and control emissions
related to coal utilization through the application ofmarket-based instruments and available technologies. It
sets standards on SOX and NOX emissions and the socalled greenhouse gases that contribute to global
warming.

資料133

GEOTHERMAL 2

CCTs of Coal-Fired Power Plants in thePhilippines
CFB

FGD

EP

BF

CCS

ECS

AP

Calaca (2x300 MW )
PC

-

-

√

-

-

√

-

Masinloc (2x300 MW)
PC

-

-

√

-

-

√

-

Sual (2x609 MW) PC

-

√

√

-

-

√

√

Pagbilao (2x350 MW)
PC

-

-

√

-

-

√

√

Mauban (1x460 MW)
PC

-

√

√

-

-

√

√

Toledo (2x40 MW)

AFB

-

-

√

-

√

-

Salcon (50 & 55 MW)
PC

-

-

√

-

-

√

√

-

-

√

√

√

√

Steag (2x105 MW)PC
APEC (50 MW)

√

-

√

-

√

√

√

UPPC (24 MW)

√

-

√

-

-

√

√

Coral Bay (11 MW)
PC

-

-

√

-

-

√

Semirara (2x7.5 MW)
PC

-

-

√

-

-

√

資料134

-

Note:
CFB – Circulating Fluidiized Bed
Boiler
AFB – Atmospheric Fluidized
BoilerPC – Pulverized Coal Boiler
FGD - Flue Gas Desulfurizer
EP – Electrostatic Precipitator
BF – Bag Filters
CCS – Covered Coal Stockyard
ECS – Enclosed Conveyor System
AP – Ash Pond with polyethylene
linerCONCLUSIONSThe country badly needs baseload generation. While we apply
multi-fuel policy, coal-fired power plants remains to be the least
cost and immediately available option in the near-term

In response, there are commitments made for additional coal-fired
capacity

Adoption of clean coal technologies is facilitated to maximize theuse of coal for power generation at this time when environment is apriority.



Development of coal mine-mouth power plant projects will facilitate
utilization of our relatively low rank coals

While there is no standard yet for carbon dioxide emissions, the concept ofcarbon reduction is being looked at as technologies are being introduced in
the country.
資料135

THANK YOU

資料136

2010. 10. 27
Project Leader Sung Chul Kim
KEPCO Research Institute
資料137

Electric Capacity & Power Generation
CCS R&D Status
CCS Strategy in Korea
Summary
資料138

Status of Electric Capacity & Power
Generation
Electricity Generation

Electricity Capacity
728

6,867

5,505 1.3%

9.5% 7.6%

24.8%

17,97017,71624.4%

75,80923,705150,95835.7%

173,508

Total: 72,491 MW

Coal

3.7%
17.9%
41.1%

32.7%

Nuclear5,562 1,092
1.3% 0.3%
15,426

Total: 422,355 GWh

Gas 資料139 Oil

Hydraulic

Renewable

Long-term Electric Power Development Plan
(Based on the 4th Electric Power Demand & Supply Plan )Capacity

100,891MW(x 1,000 MW)

93,568MW90
8062,258MW

11.6%

11.8%

70

8.8%
7.6%

4.6%

3.6%

24.6%

22.9%

31.4%

29.2%

60
50
40
30
20

26.4%
28.9%

•Renewable Energy- 2015 : 3.6%
- 2022 : 4.0%

32.6%
28.5%

27.7%

2005

2015

10
0

Nuclear

Coal

LNG

資料140

2022
Oil

Hydraulic/etc.

Plan of Electric Power Supply in Korea
NuclearCoal

LNG

Petroleum

OthersTotal(MW)Present
Capacity MW(Unit, 2008)

17,716(20)

23,705(49)

17,970
(46)

6,867
(27)

6,233

72,491

Construction
Plan MW(2009-2022,unit)

15,200
(12)

6,240
(7)

6,630
(11)

70
(1)

4,150

32,290

-

530
(3)

1,540
(6)

1,820
(13)

-

3,890

32,916(32)

29,415(53)

23,060
(51)

5,117
(15)

10,383

100,891

Fuel
Capacity

Decommission
MW(2009-2022,unit)
Total Capacity
MW(2022, unit)

資料141

資料142

Coal Import countries in Korea
45
40
35
30
25
20
15
10
5
0

Australia
CanadaChina
USA
RussiaIndonesia
Etc.
2003

2005

2007

2009

Year

Australia

CanadaChina

USA

RussiaIndonesia

Etc.

Total
(Mil.Ton)

2003

25

4

26

0.9

3

6

1

64.9

2005

29.8

4.1

18.1

0.8

3.5

12.9

0.1

69.3

2007

27.4

4.7

15.9

0.07

0.6

25.6

8.6

82.8

2009

40
(43%)

7.7
(8.3%)

4.6(4.9%)

30.9(33.2%)

1.0(1.1%)

92.9(100%)

7.3
1.4(1.5%)(7.9%) 資料143

Prediction of

Coal Demand in Korea(Unit: Mil. Ton)

Year

2006

2009

2011

2013

2016

Electricity

54.0

66.3

66.4

66.3

73.5

Steel

15.6

19

26.4

26.4

26.4

Cement &
Etc.

7.3

7.6

8.1

8.2

8.6

Total

71.9

92.9

100.9

100.9

108.5

Field

資料144

Korea is one of heavy GHG emitters
GHG Emission(M tCO2 )GHG Emission per Capita(M tCO2 /person)

World
9th

World
27th

Korea set the ambitious GHG Reduction Goal (Nov. 17, 2009)- 30% reduction below BAU* by 2020
* BAU: Business As Usual

資料145

 CCSR&D Status- Post- Combustion(Wet)

Test Bed of CO2 Capture
at Seoul Cogeneration Plant,
2tCO2/d

資料146

 Roadmap ofPost Combustion~ 20072008 ~ 2015 2016 ~ 2020

Test bed

Pilot Plant~2 tCO2/dDemonstration
Plant~ 10 MW~50 MW Verification and Absorbent screening  Development of Basic principles

new type absorbent

optimization of the Flue gas

 Validation of basic

process

characteristics
 wet & solid sorbent

principles and scale-  ~ 30 US$/tCO2
up factors
 Long term operation
characteristics

資料147

Commercial Plant
500 MW Large scale reductionof CO2 to meetglobal guideline
 < 20 US$/tCO2



Post-Combustion(Dry Sorbent Process)1. Starting year: 2002.10
CO2 free flue gas

MHCO3

CO2,
H2O

2. Period : 2008.10~2011.03 (PhaseIII)
3. Budget : $1.5 Million
4. Status- Construction of 0.5 MW PP- Process : Fluidized Bed-Reactor- Validation of Process 25 kW BSU

M2CO3: 80-90% Removal

MHCO3

Steam
M2CO3

M = Na or K

- Solid Sorbent Development: KX35T5: Less Upstream Gas Constraint

Flue gas: Cheap Material
資料148: Better Sorption Capacity (6~10 Roadmap of Post-Combustion (Dry)Industry

Steel, Chemical, Cement
CO2 Capture Technology
Deploy25 kW
BSU(2008)

0.5 MW
Pilot
Plant(2010)(2015~)

Accelerating

10 MW
Demo.
(2014)

Commercial
300~500 MW
Commercial
scale(2018)

Power Plant

資料149

500 MW
Deploy(2020~)CCS Oxy-Combustion Technology

 Oxidant for Coal : Air → Pure Oxygen Condensation of flue gas : capturing most of CO 2
 Recycle of flue gas : matching for heat transfer characteristics
資料150

 Proposed Demonstration Project
CO2 CaptureRetrofitting the Young-dong unit #1
 Current : 125MWe . Domestic Anthracite Decommission by 2013
 Retrofitting for Dual –Firing System

100MWe Class Demonstration
 Detaile Design by 2013
 Construction by 2015
 Demonstration : 2016~2018

資料151

Complete two capture-storage combined demonstration project
on a scale of 100MW until 2020
promote CCS commercialization and reinforce leading role ininternational society

Capture [Pilot scale → Front-End Engineering Design → Large-scale demonstration]
 Gradually proceed with project planning after considering market maturity
and technology level of each capture technology

Storage Promote storage demonstration of over 1 million ton annually from 2017
after securing a large scale storage site by 2015( each holds more than 1
bil ton) Select demonstration target sites such as Ulleung basin and decide on final
資料152
demonstration site by 2015

$1.92 billion needs to be invested from 2010 to 2020
 Government-Private sector Investment Ratio- Government: 1 billion dollar (52%), Private: 0.92 billion
dollars(48%)* large-scale demonstration in capture (government 20%, private 80%)
large-scale in storage demonstration (government 60%, private 40%)

 Investment cost
- Technology development of next generation: $ 200 million (10%)* Development of Capture technology, Capture & Storage research, Conversion
technology, etc.

- Demonstration for commercialization: $1.6 billion dollars (84%)- Environment administration and establishing foundation: $117 million
(6%)
資料153

CCS


Korea will carry on the investment in CCS technology fordevelopment and commercialization as well as using CCS as
the main measure in reducing GHG emission

 Korea expects reduction of CO2 emission annually by 32million
tons by 2030

Coal Policy• Diversification of coal importing countries
 Canada, USA, South Africa• Investment in oversea coal Mine(Off- Takes)• Improvement of Low Rank coal for Blending• Diversification of coal procurement method
資料154

（3）セッション 1B

資料155

Coal Policy and CO2
Reduction in Australia
APEC Clean Fossil Energy Technicaland Policy Seminar 2010
Fukuoka, Japan
27-29 October 2010
John Karas
A/g General Manager
Low Emissions Coal and CO2 Storage Branch
Clean Energy Division
Department of Resources Energy and Tourism
資料156

Greenhouse Commitments and Coal•

Australia is committed to emission reduction targets‾‾•

By 2020: 5-15% below 2000 levels• 25% for strong global commitment
By 2050: 60% below 2000 levels.

These targets are a major challenge for Australia given
our heavy reliance on coal
‾
‾
‾
‾
‾

Coal provides 80% of electricity and 32% of emissions
Reliance on coal will decline but coal will continue to be themajor source of power
Improvements in coal generating efficiency importantBut carbon capture and storage (CCS) essential to achieve
major cuts in emissions
Responsibilities as a major international energy supplier.
資料157

CCS Policies

Legislative
Certainty

Knowledge &Collaboration

Storage

CCS

Engagement

R&D

Demonstration
資料158

Community Acceptance

Australian Government CCS
Initiatives• National Low Emissions Coal Initiative(~$400 million)• Stakeholders engaged to develop andimplement a national strategy• National Low Emissions Coal R&D• Medium scale projects• CCS Flagship Program (~ $2 billion)• Global CCS Institute (up to $100 million pa)• CCS Ready and emission standards
for new coal fired power stations
資料159

Pilot Projects• Otway pilot storage project• PCC Pilots - Loy Lang, Munmorah, Tarong,
Hazelwood, China
Medium Scale Demonstrations• Proposed PCC demonstration projects• Oxyfuel retrofit at Callide A power station
Large Scale• CCS Flagships Program• Wandoan: IGCC + CCS• Zerogen: IGCC + CCS• Collie South West Hub• CarbonNet Hub• Gorgon LNG Project• HRL IDGCC• Nippon Steel Engineering ECOPRO
資料160

CONCLUDING COMMENTS• Coal will continue to play an important role inmeeting expanding energy demand in APEC
• But only if its greenhouse footprint is cut• The early development of CCS is crucial• But major challenges in putting the CCS
puzzle together• APEC - Key role in international
collaboration and knowledge sharing

資料161

APEC CLEAN FOSSIL ENERGY TECHNICAL AND POLICY SEMINAR 2010
FUKUOKA, JAPAN27 OCTOBER 2010

COAL POLICY AND CO2 REDUCTION IN INDONESIA

Directorate General of Mineral, Coal And Geothermal

Ministry of Energy and Mineral Resources of the Republic of Indonesia
資料162

1

TOPICS CURRENT CONDITION
 COAL MINING POLICY CO2 REDUCTION

資料163

CURRENT CONDITION
 Indonesia geological prospects of coal is still very promising.
 In the last five years there was an increase of: Coal production 14 % per-year
 Investment 16 % per-year State income (tax and non-tax) 34 % per year Coal production about 256 million ton last year (almost doubled
compared to 2004 coal production). Production came from 47 Coal
Contract of Work (CCoW), State Owned Company (TBA) and Mining
Authorization (KP holder, now called IUP). About 70-75% of coalproduction was exported to many countries
 The Law No 4/2009 about Mineral and Coal Mining will bring to the new
direction of mining operation (DMO obligation, added-value obligation,state revenue optimalization, etc).
資料164

CURRENT CONDITION
COAL RESOURCES AND RESERVES
12.43%

0.96%

51.83 b.t

52.53 b.t

Low Rank

0.23 b.t

SUMATRA

20.22%

0.002 b.t

Medium Rank

0.15 b.tHigh Rank
Very High Rank

0.01 b.t
Resource: 104,756 BT

Reserves: 21.13BT

66.39%

資料165

Source: Geological Agency of MEMR, December 2008

4

CURRENT CONDITIONREALIZATION AND PLANNING OF COAL
PRODUCTION, EXPORT AND DOMESTIC

Realization

Planning

資料166

5

COAL POLICYPOLICY AND REGULATORY (1):LATEST REGULATORY PROGRESS Government Regulations : Government Regulation No 22/2010 Regarding Mining Zone
 Government Regulation No 23/2010 Regarding Mineral And Coal Enterprises Activity
 Government Regulation No 55/2010 Regarding Supervising And Controlling Mining
Activity Reclamation and Post Mining (final process in State Secretary)
 Minister Regulation and Decree: Minister Regulation No 28/2009 regarding Service Mining Company
 Minister Regulation No 34/2009 regarding DMO Obligation for Mineral and Coal Minister Regulation No. 17/2010 regarding procedures for stipulating the benchmark
price and sale of mineral and coal
 Minister Decree No 1604/2010 regarding Minimum Percentage of Domestic Coal
Supply 2010
 Minister Decree No 2360/2010 regarding Minimum Percentage of Domestic Coal
Supply 2011
資料167

COAL POLICYPOLICY AND REGULATORY (2):STRATEGIC COAL POLICY
1. To increase the role of coal in the framework of national energy development.
This is obviously mentioned in the Blueprint of National Energy Management and
The Presidential Decree No. 5 of 2006 about National Energy Policy that by 2025
the use of coal in national energy mix will be 35% including 2% of coalliquefaction, while oil will be below 20% at that time. At present, the use of coal inenergy mix is about 18 %, while oil is around 50%.
2. To maintain the security of Indonesia long-term coal supply-demand Coal DMO
 Coal Pricing
 Coal Export
3. To develop all types of coal
 Monitoring, supervision, country revenue Clean coal technology
 manpower development
 Utilization /processing of low rank coal (UBC, gasification, liquefaction, mine
mouth powerplant) Conservation
資料168

COAL POLICYTHE STRATEGY OF COAL MANAGEMENT POLICY(All Coal Grade Should be Mined and Optimally Utilized)

COAL
RESOURCESHIGH RANK(BIT, SUB.BIT)EXPORTMEDIUM RANK
(SUB.BIT)DOMESTICUSEUPGRADINGMMPPGASIFICATION
LIQUEFACTION
POWER PLANT
INDUSTRY

LOW RANK(LIGNITE)

MMPP – Mine Mouth Power Plant
資料169

COAL POLICYSTRATEGIC POLICY 1: THE ROLE OF COAL
2008
Nat. gas28,6%

Geothermal
1,6%

Coal
18,8%

Geothermal
5%

Water
2,7%

Biofuel5%
Renewable
5%

2025
CTL
2%
GAS
30%

Oil
48,4%
OIL

20%
Based on Law
Precidential Decree No. 5/2006
Instructions Precidential No. 2/2006
COAL
33%

Coal
Gas
Oil

資料170

COAL POLICYSTRATEGIC POLICY 2: SUPPLY-DEMAND POLICY(DMO AND COAL PRICING) -2

Coal Pricing Policy• The government has to set an Indonesian Coal Price Reference(ICPR/ HPB), to:- be a reference for producer and consumers, mainly domestic
consumers.
- optimize on state revenues from coal.
- support domestic coal security of supply.
• ICPR will cause the coal prices relatively "uniform" (related to thequality), so that domestic coal supply and export is similarly
attractive.
• At present, government has routinely issued the monthly coal pricereference and sent it to coal mining players (local government andcoal companies).
資料171

COALCoal
POLICYANDREGULATIONDMO andPrice
Policy• Coal DMO as an obligatory for all coal mining
companies (IUP and PKP2B).
• Minister set up policy on coal DMO and price(Indonesia Coal Price Reference/ICPR) coordinate
資料172
with the governor/regent/mayor

11

CO2 REDUCTIONOUR COMMITMENT ON REDUCING GHG EMISSION

By 2020 we will reduce our emissions by

26 %(Business As Usual)

or

41 %
Source:President SBY’s speech at G20 Leaders Summit
25 September 2009, Pittsburgh, PA(With International Support)
資料173

12

CO2 REDUCTION
About 80% of Indonesia’s GHG Emissions
Come from the Land Use, Land Use Change, Forestry (LULUCF) Sector

資料174

Source: UNFCCC, WRI, IEA, EPA, McKinsey

13

CO2 REDUCTION
NATIONAL ACTION PLAN (NAP)

NAP
Adaptation

Mitigation

Water
Resources

Agriculture

Coastal,Marine &Fish.

Infrastructure

HealthForestry &Biodiversity

Source:National Action Plan Addressing Climate Change, 2007

資料175

14

Energy

LULUCF

Marine &Fisheries

LULUCF—Land Use, Land Use Change, Forestry

CO2 REDUCTION

COAL MINING-RELATED NAP

Energy• Energy Diversification (energy mix)
• Energy Conservation• Clean Coal Technology• Coal-Power Plant: Supercritical• Coal-Power Plant : IGCC
• Carbon Capture and Storage (CCS)LULUCF• Reclamation and PostMining Reclamation

Forestry &Biodiversity• Biodiversity Conservation

資料176

15

CO2 REDUCTIONEFFORTS TO REDUCE EMISSIONS – RELATED NAP
 To realize the reduction of GHG emissions in accordance with the target of
26%, have been developed various interventions and action plans tocompiled climate change mitigation policies and programs of which was
entrusted to the Directorate General of Mineral and Coal, the Ministry ofEnergy and Mineral Resources in the form of Emission Reduction Program
Deforestation and Degradation Plus (+ REDD: Reducing Emissions from
Deforestation and Degradation Plus).
 To reduce deforestation and land degradation, Directorate General of
Mineral and Coal has a conversion program which is attempting to achieve
the reforms planned for the sustainable development of the mining sector.
Reform of the mining sector which will be mining regulations is to improve
legislation in the field of mining-related REDD +, enhanced mining plan,increased supervision of mining and reclamation permits and the increasein ex-mining forests.
 In the Five Year Strategic in order to mitigate climate change plan,
Directorate General of Mineral and Coal will be reclaimed area of 31,400 hawith the assumption to reduce emissions by 2.763 million tons of CO2 until
2014 (by COW and CCOW)
資料177

16

THANK YOU
www.djmbp.esdm.go.id

資料178

DOMESTIC COAL DEMAND IN 2010*)
NO

COMPANYI

POWER STEAM
PLN
IPP
PT FREEPORT INDONESIA
PT NEWMONT NUSA TENGGARAMETALURGIPT INCOPT ANTAMCEMENT, FERTILIZER AND TEXTILECEMENTTEXTILES AND TEXTILE PRODUCTFERTILIZER
TOTAL

II

III

TONASE (MILLION
TON)

%

GCV

45,1
9,1
0,78
0,52

69,4
14
1
0,8

4.000 - 5.100
4.000 - 5.100
5.650 - 6.150
5.900

0,16
0,15

0,2
0,2

≥ 6.000≥ 6.000

7,6
1,2
0,35
64,96

11,7
1,8
0,5

4.000 - 6.200
5.000 - 6.500
4.000 - 5.000*) based on the insert from end user
資料179

18
18

DOMESTIC COAL DEMAND IN 2011*)

NO

COMPANYI

POWER STEAM
PLN
IPP
PT FREEPORT INDONESIA
PT NEWMONT NUSA TENGGARA

II

III

TONASE (MILLION
TON)%

GCV (GAR)

55.82
8.97
0.83
0.47

70.69
11.36
1.05
0.60

4.000 - 5.200
4.000 - 5.200
5.650 - 6.150
5,200

0.19

0.24

5,000

0.14
0.20

0.17
0.25

5.900
≥ 6.000

8.86
1.97
0.92
0.60
78.97

11.22
2.49
1.16
0.76
100.0

4.100 - 6.300
5.000 - 6.500
4.000 - 5.000
4.500 - 5.500

PT PUSAKA JAYA PALU POWER
METALURGYPT INCOPT ANTAMCEMENT, FERTILIZER,PULP AND TEXTILECEMENTTEXTILE AND TEXTILE PRODUCT *)FERTILIZER
PULP
TOTAL
資料180

EFFORTS TO REDUCE EMISSIONS – RELATED NAP

Volume Activity (Ha)ActionPlan

PeriodPost
MiningLand
Reclamation20102014

TargetIndicator
Emission
Absorption
2014:

2010
6.000

2011

2012

2013

2014

Total

6.200

6.300

6.400

6.500

31.4002.763
Million ton
CO2

資料181

Coal Policy and CO2
Reduction in Thailand
Dr. Boonrod Sajjakulnukit
Joint Graduate School of Energy and Environment (JGSEE)King Mongkut’s University of Technology Thonburi (KMUTT)APEC Clean Fossil Energy Technical and Policy Seminar 2010

FUKUOKA, JAPAN

27-29 OCTOBER 2010
資料182

Outline• Energy Situation• Coal Situation• Coal Policy &CO2 Reduction• Conclusions

資料183

Thailand Energy Situation in 2009…..Thailand is NET Energy Importer…..
In 2009, Energy Expenses 47 billion USD (import 58%)
Total Commercial Energy Use 1.656 million barrels (oil equivalent) of per day
New
and
Renew
8%
Coal
11%

TraditionalRE
6%

Natural
Gas
40%

Oil
35%

Primary Energy*NRE includes Large Hydro

Agriculture 5%
Transportation
35%

Industry 38%

Residential and Commercial 22%

Energy Use by sector

資料184

3

Coal Demand in Thailand
In 2030: Total Demand = 48.7 million tons
(Industry: 15.2; Electricity: 33.5)

Coal Demand ('000 tons)

60,000

Projection

Total

50,00040,000Electricity

30,00020,000Industry

10,000From PDP2010,
9 Coal-fired
power plant withtotal capacity of
7,200 MW will be
operated each year
from 2019 to 2030.
(19.62 million tons)

Electricity

Source: Electricity Generating
Authority of Thailand

Industry

2028

2025

2022

2019

2016

2013

2010

2007

2004

2001

1998

1995

1992

1989

1986

0
Y

Total

2009: Total Demand = 34.2 million tons
(Industry: 12.7; Electricity: 21.5)
資料185

Fuel Mix for Power Generation
Renewable 1.7%

Renewable 1.45%

Imported Coal 8.7%

Imported Coal 8.2%
Heavy Oil 0.4%

Natural Gas
71.77 %

Lignite 11.6%

Heavy Oil 0.1%

Natural Gas
72.8 %

Lignite 10.3%

Hydro 4.8%

Hydro 5.1%
Lao PDR 1.1% Diesel 0.02%
EGAT-TNB
0.1 %Lao PDR 1.6% Diesel 0.03%
EGAT-TNB
0.15 %

January 1 – March 31, 2010
38,821.6 GWh

January 1 – December 31, 2009
145,233 GWh

Source: Electricity Generating Authority of Thailand
資料186

Coal Imported of Thailand, 1999 - 2009
Unit : thousand tons
18,00016,00014,00012,00010,000
8,000
6,000
4,000
2,000
0
1999

2000

2001

2002
Total

2003

2004

IPP

SPP

2005

2006

2007

2008

Industry

Source : Energy Policy and Panning Office
資料187

2009

Thailand Power Development Plan
List of Projects from 2010 – 2021

MW
5,000

Foreign Purchase

4,500

Domestic Purchase

4,000

Retired Capacity

EGAT
SEC#1-2
NPSC#1-2
SPP, VSPP
RW

3,500
3,000
2,500

NT 2
SPP, VSPP
NB_CC 1

2,000
1,500
1,000
500

NPSC#3-4
PGSC#1-2
SPP, VSPP
WN_CC 4
CHN_CC 2
RW

920

NNG 2
GHECO-One
SPP, VSPP
RW
THB_Ex
SPP, VSPP
RW
597

HSA 1-2
SPP, VSPP
RW

1,078

982
1,301

931
437

(70)

PPB_TH 1

(500)

860

(1,052)(748)(1,175)

Foreign
SPP, VSPP
RW

499

450

511

446

(494)

BPK_TH 1-2

2011

2012

2013

2014

2015

808

1,861
1,022

(185)

(200)

(681)

BPK_ CC 3(1,529)

BPK_ CC 4
NPO_CC 1
TECO
SB_ CC 1
NPO_CC 2

2016

2017

2018

Year
資料188

515

460
447

(2,000)

2010

600

600

Ry_CC 1-4

(1,500)Foreign
SPP, VSPP
Nuk 1
RW
600

440

PPB TH 2
KN_ CC(1,000)Foreign
SPP, VSPP
Coal 1RW

NNG 3
SPP, VSPPLTK 3-4
RW

2,777

1,618

670

0

2,152

220

547

HSA 3
MYGD 1-3
SPP, VSPP
IPP_South
RW

Foreign
SPP, VSPP
Nuk 2
Coal 2RW

Source: Electricity Generating Authority of Thailand

2019

2020

2021

Thailand Power Development Plan ( Con.)
List of Projects from 2022 – 2030

MW

Foreign
SPP, VSPP
Gas_CC 2-6
Coal 3

6,500
6,000
5,500

600

5,000

506

Foreign
SPP, VSPP
Nuk 5
Gas_CC 11-12
Coal 6-7
Foreign
SPP, VSPP
Gas_CC 8-9
Coal 4-5

4,500
4,000
3,500
3,000
2,500
2,000
1,500
1,000
500

Foreign
SPP, VSPP
Gas_CC 1
RW

4,800

Foreign
SPP, VSPP
Nuk 3

600

600

654

508

Foreign
SPP, VSPP
Nuk 4
Gas_CC 7533

600

Foreign
SPP, VSPP
Gas_CC 13
Coal 8519

Foreign
SPP, VSPP
Gas_CC 10

600
523
3,200

4,200

600

600

Foreign
SPP, VSPP
Coal 9

539

600
719

529

1,800

1,600

1,000

836

600

800

800

0
(500)
(1,000)(726)(3,653)

BPK_TH 3
THB
EPEC
WN_CC 1-3
SB_CC 2
BPK_TH 4(1,500)(2,000)(2,500)(820)(2,664)(145)

MM_TH 7

MM_TH 4

(2,056)(808)

Glow IPP

RB_CC 1-3

(396)
(270)

MM_TH 8HHPC
MM_TH 9Foreign Purchase
Domestic Purchase
EGAT
Retired Capacity

RB_TH 1-2
IPT
MM_TH 5-6

(3,000)(3,500)(4,000)

2022

2023

2024

2025

2026

2027

2028

Year
資料189

Source: Electricity Generating Authority of Thailand

2029

2030

Percentage Share of Energy Requirement(by Fuel Type)
GWh

PDP2010360,000

DieselRenewable

320,000

Heavy OilPower Import

280,000

Natural Gas
Coal

240,000

Lignite6%

Nuclear200,000

Hydro
160,000
7%

5%
7%

5%
7%

5%
6%

6%

6%

14%
6%
14%
6%
13%
8% 13%

6%
15%

54%
68% 66% 64% 64% 64% 62% 59% 59%

40,000
8%

0

9%

9%

9%

2010

2014

2015

2012

2013

17%

17%

18%

59%

49%

48%

47%

6%

18%

43%

12%

9%

8%

8%

8%

7%
3%

2016

2017

2018

2019

2020

資料190

13% 13%

18%

44%

6%

19%

18%

39%

39%

39%

46%

17% 16%
15% 14% 13%
6%

6%

19%

58%

11%
10% 10% 11% 12% 11% 11% 10%

11% 11% 10% 10%

2011

16%

17%

6%

45%

120,000

80,000

6%

6%

6%

6%

6%

6%

6%

5%

4%

4%

19% 20%
4%

3%

21%

2%

7%

7%

6%

6% 6%

8%

11% 10% 10% 12% 11% 11%

2021

2022

2024

2025

2023

2026

Source: Electricity Generating Authority of Thailand

2027

2028

2029

2030

Yr

Coal Policy & CO2 Reduction• Coal is an essential option for the Country’s Energy
Security.
• Future use of coal, more environmental concern.

• CCTsSupercritical PC, IGCC+CCS?
Cogen.
CFBC
Industry

CWM, Gasification,
Mini CP• Join ADB Project; Determining the Potential
for Carbon Capture and Storage in Thailand
資料191

Coal Policy & CO2 Reduction

Official CO2 reduction target has yet been announced----But--資料192

Co2 Emission in Energy Sector
2.58
2.27

2.05

2.35

ที่มา : 1. - 12. The Energy Data and Modeling Center (EDMC), Japan
資料19313. ระบบฐานขอมูล EPPO-EMS
12

EE Plan 2030
25% Energy Intensity Reduction in 2030
152,100

EI2005 = 16

140,000

BAU∆ = 33,400

EI2030 = 12

118,700

120,000

100,000

Saving80,00060,00061,634

Saving needed = 33,400 ktoe
or 22.0% of BAU in 2030
*GDP2030 at constant price 1988 = 9,890 billion baht
資料194

2030

40,0002005

Final Energy Consumption (ktoe)

160,00013สรุปและเปรียบเทียบศักยภาพประหยัดพลังงานไฟฟา
EGAT & JGSEE [EE2030]��� �� ��̣� � ���� � ��
�� BAU (11 ������� 2553) � ����� ������� �� �� ơ��� 20 � 

Save 9,000 MW
39 million Ton of CO2

450,000
400,000

BAU - JGSEE

350,000

ฐาน 2005

BAU - Load
11 Aug 2010

300,000

Saving250,000
200,000
150,000รายละเอียด LoadForecast & EE2030_2010-10-12.xls, sheet [LFC EE 2030]

100,000

BAU - Load 11Aug2010

Total - Saving

BAU - JGSEE (��� 2005)* BAU - JGSEE : เริ่มที่ปฐาน 2005
資料195
* BAU - Load 11 Aug 2010 : เริ่มปฐาน 2010 ลบผลประหยัดจากการดํ
าเนินการอนุรักษพลังงาน ในชวงป 2548- 2553 จํานวน 24,674 GWh 14* Saving : BAU - Load 11 Aug 2010 ลบผลประหยัดตามแผน EE 20 ปThailand Renewable Energy
Committed to the development
Developmentof low-carbon society
Government
Funding
On R & D & D
Activities

Encouraging
Private-Led
Investment

15 years RE-Development Plan

Target 14 % of RE in Total Energy Consumption
By 2022

Solar + Wind
1,300 MWSupporting
Schemes

Small + Mini
Hydro
320 MW

Biofuels

Bio Energy
Biomass

BiogasMSW

4,000 MW160 MW

120 MW• Feed-in Premium (“Adder”) on top of regular tariff• BOI Tax incentives scheme (8 yr. Tax holiday)• Some direct subsidy (10-30%) on Biogas,MSW,Solar-hotwater projects• Soft Loans for RE+EE investments
資料196• Government Co-investing scheme (“ESCO Fund”)• Ethanol• Biodiesel
20% Oil substitution• Abundant Supply• Market driven• Pricing Strategy topromote high-RE-Fuels(E10,E20,E85 and B5)

15

Conclusions• Coal is an essential option for the Country’s
Energy Security.
• Future use of coal is increasing, more efficientand less CO2 emission.

• It is expected that a national target for
CO2 reduction will be announced by
next year.
• Major contribution will be from EE, RE
and higher efficiency of power
generation especially from COAL.
資料197

資料198

GHECO-One Power Plant Project
•
•
•
•
•
•
•
•
•

Picture taken in Aug. 2010
資料199

• Project Information
Project Name : GHECO-One Thermal
Power Plant
Gross Capacity : 700MW x 1 Unit
Plant Type : Conventional Supercritical Coal
Fired
Plant Site : Mat Ta Phut Industrial Estate,
Thailand185 km from Bangkok
Owner : GHECO-ONE Company Limited
Supply Scheme : EPC Full Turnkey Work
COD: Nov 2011
Current Status : Under constructionPerformance Parameters
Site Condition
Elevation

Power Generationm

3.45

Gross Output

MWe

700

mbar

1010

Net Output

MWe

660

Ambient Air
Temperature

oC

32.2

Relative Humidity

%

75

kg/s

596.7

Main Steam Temperature

oC

569

Ambient Air Pressure

Steam Conditions at
VWO
Main Steam Flow Rate

Emission Limits*
NOx

ppmv

56

Main Steam Pressure

bar

251

SOx

ppmv

53

Reheat Steam Flow Rate

kg/s

485.5

CO

ppmv

160

Reheat Steam Temperature

oC

569

Particulates

mg/Nm

55

Reheat Steam Pressure

bar

50.7

oC

289

3

GHECO-One Coal Demand 2.1 Million ton per
year
資料200

* 7% O2-dry at 25 oC

Feedwater Temperature

（4）特別講演 4

資料201

Clean Energy in Asia

Hideo Nagashima
Kyushu University

資料202

-p.3-

Change in oil prices$82/bbl$74/bbl10.10.12
08.10.21

プレミアムWorld–wide rush for coalMore deposit than petroleum

economic progressin developing countries

Energy White Paper 2008
http://www.enecho.meti.go.jp/topics/hakusho/index.htm
資料203

-p.6-

North East Wind
Acid Rain
Yellow
Sand

SOx
NOx

Aerial pollution by photochemical smog
coming from China in May 2007. Kyushu
area was highly polluted.
(Ref. National Institute for Environmental
Studies)
資料204

-p.7-

EU 12%
RussiaJapan

Saudi Arabia

CanadaGermany
BrittainSouth Africa
Others

Italy

MexicoAustralia

Iran

Korea

Million ton CO2

China

USA

France

India

China

CO2 Emission from the Generation of Energy(2005)USA(RITE)

Outlook of CO2 Emission
資料205

In 1911, Kyushu Imperial University was establishedThe first centennial anniversary: May, 2011

Kenjiro Yamakawa
The First President
April 1911 ～ May 1913

“Learning for its own sake”

Setsuo Arikawa

The Present President
October 2009 ～As a world-class Center of Excellence open toAsia, Kyushu University is expected and destined
to develop primary education, research, andmedical activities.
資料206

Undergraduate
Schools (11)Letters, Education, Law, Economics, Sciences, Medicine, Dentistry,
Pharmaceutical Sciences, Engineering, Design, Agriculture

Graduate
Schools (18)

Humanities, Sciences, Social and Cultural Studies, Human-Environment Studies,Law, Law School (Professional), Economics, Sciences, Mathematics,
Systems Life Sciences, Medical Sciences, Dental Science, Pharmaceutical
Sciences, Engineering, Design, ISEE, Engineering Sciences,
Bioresource and Bioenvironmental Sciences, Integrated Frontier Sciences

Research
Institutes (3)Medical Institute of Bioregulation, Research Institute for Applied Mathematics (RIAM),
Institute for Materials Chemistry and Engineering

Hospital (1)Libraries (6)Kyushu University Hospital (25 medical departments and 4 dental departments)
Central Library, Medical Library, Design Library, Science & Technology Library, etc.

7,285 university staff【11 board members, 2,186 faculty, 2,714 administrative staff and technical staff, others; 2,374】
18,765 students【11,752 undergraduate students, 3,819 master’s students, 2,747 PhD students,
445 professional course students】
1,713 international students【140 undergraduate students, 1142 graduate students, others; 431】
資料207

■ Location of Ito Campus

Current
Ito Campus
４７ha

Hakozaki Campus
Hospital Campus
２４ha
AirportIto Campus
Ohashi Campus
Chikushi Campus（Approx. ２７５ha）
Fukuoka City ２４３ha
Shima Town ３１ha
Maebaru City １ha

7
資料208

8

■ Ito Campus

Ito Campus received the Fukuoka Urban Beautification Award in 20098
資料209

■ Our Strategies

North America

EuropeU.S

Asia
・ Reinforce the cooperation among universities
・ Formulate networks
・ Show our presence as Asia9
資料210

-p.10-Future Directions of Kyushu Univ. and Support System for G-COE
Prof. T. Kajiyama, the former President of Kyushu University

Targets:Environment,
Environment,Energy,
Energy,andandHuman
HumanResources
ResourcesDevelopment
Development
Targets:

Kyushu University
４＋２＋４ Action Plan
4: Missions • Activities
Research, Education
Contributions to Society &International Society
New Fields
efficient carbon
resource utilization

2: Future Directions
New Science Fields
Oriented toward Asia

Coal-Based Eco-Innovations
Novel Carbon Resource Sciences

4: Support Based on
Performance Evaluation
Budget allocation
Improvement of facilities andspacesHuman resources measures
Increasing time for education
and research

Collaboration
with Asia

2007：theEast
EastAsian
AsianEnvironmental
Environmental
2007：theProblemsProject
Project
Problems

2007：EnergyCampus
CampusPlan
Plan
2007：Energy(Present）CarbonResource～H
Resource～H～Atomic
Fusion（Future）
2～AtomicFusion（Future）(Present）Carbon
2
資料211

-p.122007～200９：Program for Core Workers in Effective
Utilization of Coal and Other Fossil Resources
related national
projects led by
Kyushu Univ.

1980

coal liquefaction

1990

Institutes for coal andcarbon resources

Next-generation Fundamental Technology for Gasification

New Coke Production Process（Scope21）

2000

2008
2008：International Education and ResearchCenter for Carbon Resource Science

Science & Engineering: Res. Inst. Ind. Sci.→Inst. Adv. Mater. Stud. →Inst. Mater. Chem. Eng.
Economics: Res. Inst. Labor →Coal Information Center →University Manuscript Library

資料212

Research projects by researchers of Kyushu University and industry
e.g. Innovative Zero-emission Coal Gasification Power Generation Project (NEDO)

資料213

Joint project with Indonesia (Hayashi, Hirajima, JST)
Scientific Platform of Innovative Technologies for
Co-Upgrading of Brown Coal and Biomass

brown
coal

30 billion t

CCTbiomass> 10 millon t

Coaks

gasification

Joint project with Kyushu Univ.-Kyushu Electric Co. Ltd.-Victoria State Australia
Japan-Australia International Collabolative Research
for Advanced Utilization of Brown coal
brown
brown
coal
coal

gasificgasification
ation

electricity
electricity
synthetic
synthetic gas
gas

CCS
chemicals
chemicals

資料214

-p.9-

Novel Carbon Resource Sciences:- Coal-Based Eco-Innovations Group Representative: Prof. Hideo NAGASHIMA(Inst. Mater. Chem. Eng.; Dept. Mol. Mater. Sci.,
Interdisc. Grad. School Eng. Sci., Kyushu Univ.)

Kyushu University• Interdisciplinary Graduate School of Engineering Sciences:– Department of Molecular and Material Sciences– Department of Applied Science for Electronics and Materials– Department of Earth System Science and Technology– Department of Energy and Environmental Engineering• Graduate School of Engineering:– Department of Earth Resources Engineering– Department of Chemical Systems and Engineering• Graduate School of Economics:– Department of Economic Engineering• Institute for Materials Chemistry and Engineering• Research Institute for Applied Mechanics• Art, Science and Technology Center for Cooperative
Research

Fukuoka Women’s University
Department of Living Environmental Science
資料215

Coal = larger recoverable reserves,
but severer environmental load

-p.11Kyushu University = rich history of leading coal research, future plans for an “Energy campus”
Northern Kyushu ＝ gateway to Asia, many fossil-resource related experimental facilities

Core Collaboration

Bandung Institute of Technology,
Indonesia
Shanghai Jiao Tong University, China
Korea Institute of Energy Research,
South Korea
Curtin University of Technology
Australia
Institute for Indian ******

International
Collaboration

Fukuoka Women’s University

Central Research Institute forElectric Power Industry
Kyushu Electric Power Co., Ltd.

Network

Regional Collaboration
Kyushu Institute of Technology,
Kyoto Univ., Hokkaido Univ.,
Gunma Univ.,

More indiscriminate

資料216

Academic-industrial
Collaboration
Power industry, Steel industry
Engineering, Auto mobile,
Chemical industry

-p.22Universities, companies, overseas Institutes, International organizations

diverse career opportunities
Innovative Young Scientists Education Program

Organizing G-COE
Intn’l Symposium

Research Proposal
Training

Master Course

Consecutive Course
Program from M2

Ph. D. Course

M2

research

practical
On-the-job Training
for real-situation

planning
interdiscussion national

G-COE Young
Researcher Program

Ｇ-ＣＯＥ
Postdoctoral（Adjunct
Research
Associate）

Plural supervisor system
Ph. D. Education Program

Novel Carbon Resource Sciences Education Program
M1

Internship（companies,
overseas institutes）

main (long-term) / sub(short-term) on-thejob training
Fieldwork（factories,
overseas）
Entry at D1-levelfrom other departments
and universities

Advanced Basic Course at the Graduate School

Novel Carbon Resource Sciences Education Program①consecutive course program from M2, ②novel carbon resource sciences-related subjects and practical English
training are mandatory, ③plural supervisor system within the Ph. D. program, ④Ph. D. students will take leadership in a
research proposal training program and a young researcher program, ⑤organizing and hosting an international
symposium by students, ⑥long/short-term internship and fieldwork at institutes or companies abroad →to foster
independent advanced researchers with more diverse career opportunities
資料217

-p.8-

futureocean

Natural Carbon Cycle(+ human-driven carbon cycle
subsystem)

2100

forestcarbon resource consumption in the future= cycle capacity on Earth + renewable carbon resources
toward ideal carbon resource usage for the futuretechnology
renewablecarbon
carbonresources
resources
renewable(wood-basedbiomass,
biomass,etc.)
etc.)
innovations for (wood-based
new energy

bestmix
mixof
ofenergy
energybest
resources
resources

technology
innovations forenergy saving

unconventionalcarbon
carbonresource
resourceusage
usage
unconventional

near
future2030

a realistic
solution in thenear future

expandedcoal
coalutilization
utilization
expanded
improvedenergy
energyefficiency
efficiency
improved
environmentalmeasures
measures(CO(CO2storage)
storage)environmental
2

global environment protection

present
2000

higher efficiency ofcoal usage

Novel Carbon G-COE

materials development
for energy saving

consumption of carbon resources = CO2 emission > cycle capacity on Earth
資料218

Kyushu University Hydrogen ProjectInternational Hydrogen
Development
Energy Forum

Hydrogen Town
(150 fuel cell systems installed)

Hydrogen Highway WPI “International Institute(Hydrogen station network) for Carbon-Neutral Energy
Research （I2CNER)”(Truly-international research institutefor low-carbon energies)(International conference)

Dept. for Hydrogen
Energy Systems

Expansion(Unique graduate school)

Hydrogen Energy
Advanced
Technology
Exhibition(EXPO for hydrogen energy)

Demonstration Facility
for Future Energies(For demonstration projects)

More than 200 researchers,>5000m2 research area,for hydrogen andfuel cell technologies
International Res.
Center for Hydrogen
EnergyAIST,HYDROGENIUS

INAMORI Frontier
Research Center(Research center for future science)(Res. Center for
Hydrogen related materials)(Incubation of hydrogen and
FC technologies)

Hydrogen Energy Test ＆Research Center

21st Century
COE Program:(“Integration
Technology of
Mechanical Systems for
Hydrogen Utilization”)

2003

2004

(Support center for “hydrogen industry”)

Fukuoka Strategy Conference for
Hydrogen Energy(Collaborations with >450 corporate members)

2005

2006

2007
資料219

2008

2009

2010

World Premier International Research Center Initiative (WPI) Program, MEXTInternational Institute for Carbon‐Neutral Energy Research, Kyushu Univ.
(Director: Prof. Sofronis)

CO2 in Earth and Ocean

H2

Risk Management of CO2 Capture & Storage

 Production, Storage, and Distribution

Optimum andIntelligent Material
Transformations

EfficientHydrogen
Storage
Materials(waste‐free)

Hydrogen
Structural
Materials(compatible withhydrogen)

Next Generation
Fuel Cells(novel materials anddevices)

CO2 Separation& Concentration

Solar H Production
Artificial Photosynthesis(low energy
separation)

Thermophysicalproperties (H2, CO2)

CO2 Geological
Storage

Understanding Interface‐gas reactions
absorption, adsorption,
dissolution, diffusion,
reaction, conduction, etc.

AtomicMatter Macro
molecular ‐ ‐ earth, ocean
Spatial scale

Nanoseconds ‐ ‐ ‐ decades(long term
behavior of CO2,
stability )CO2 OceanSequestration(CO2/Ocean‐turbulenceinteraction)

FusionTemporalof Multiple
Disciplines
scale

Bio‐
mimetics

Chemistry

Physics

Materials
Science
資料220

Mechanics

Oceanic

Science

Geo‐
ScienceThe objective of Controlled Nuclear Fusion
Research is to realize the small size andmanmade "Sun" and to utilize it as energy
source for mankind.

Q-shuUniv. Exp. with
Steady-State Spherical
Tokamak

Research Institute for Applied Mechanics(Chikushi Campus)
資料221

■ Overseas Offices of Kyushu University

London Office（U.K.）
Munich Office（Germany）

Egypt Office

•
•
•
•
•
•
•

Seoul Office （South Korea）
Beijing Office（China）
Branch Office（Seoul National University )Taiwan Office（Taiwan）
Hanoi Office （Viet Nam）
Branch Office
Bangkok Office（Mahidol University）
Branch Office（Gadjah Mada University）

Washington Office（U.S.）
California Office（U.S.）【The Main Activities of Overseas Offices】
1. To provide information about Kyushu University in respective countries.
2. To provide academic information about each country to Kyushu University.
3. To provide advice on research and educational activities at Kyushu University.
4. To provide advice on the significance and potential of collaborative research between Kyush
u University and central research institutions, companies, or local governments.
5. To support orientation sessions and other activities to attract talented international students.
6. To advise or suggest on international strategies at Kyushu University.
資料222

21

(5)セッション 2

資料223

Japanese Role at APEC
to Tackle Global Warming
Clean Coal and CO2 Reduction
Technologies
byYosihiko NAKAGAKI
Chairman of the Japan Coal Energy Center (JCOAL)
Advisor to J-POWER
toAPEC Clean Fossil Energy Technical and Policy Seminar
Fukuoka
資料224
October27, 2010

30% of the Global CO2 Emissions Is
Derived from Coal-fired Power

資料225

2

Potential for Efficiency Increase/
CO2 Curtailment Exists in Light ofWorld Coal Fleets’ Efficiency
45%

Thermal Efficiency, Gross, LHV

43%
41%
39%

J-POWER
日本
Japan
英国･ｱｲﾙﾗﾝﾄﾞ
UK, Ireland
ドイツ
Germany
米国
USA
中国
China
India
インド

37%
35%
33%
31%
29%
27%
25%
1990

1995

2000

2005

資料226

Sources： Ecofys Comparison of Power Efficiency on Grid Level 2007; and actual data for J-POWER

Design Thermal Efficiency, Gross, HHV

An Efficiencies Track Record Associatedwith CO2 Emissions Decrease

資料227

3

Share of supercritical plants in coal-fired power generation (%)

CO2 Emissions Can Be Curtailed Since
Subcritical Plants Still Prevail Globally
80
70
60
50
40

Share ofsub-criticalplants

30
20
10
0

資料228

Source: IEA Presentation “Clean Coal Technologies: An IEA Perspective”, 24th Feb 2010

4

A Case of Environmental Improvements with
Replacing Subcritical Plants
Isogo Coal-fired Power Plant

New Isogo Coal-fired Power Plant

Commenced in1967

Unit #1 Commenced in 2002, Unit #2 in 2009

3 objectives
 Repowering Cleaner

Environment

 Efficiency

Improvement■Generation Capacity 530MW（265MW×2 units）

1200MW（600MW×2 units）

60ppm
159ppm
50mg/m3N

10ppm (20)
13ppm (20)5mg/m3N (10)

■SOX

NOX
PM

Sub Critical
Efficiency (gross %HHV) 38%■Steam Condition■CO2 emission intensity（CO2/KWh-net) 100 (base)
資料229

Numbers in （ ） are for Unit #１

Ultra Super Critical
43%

83

5

Skilful O&M Are Crucial to Maintain
Efficiency Through Plant Lifetime… 40 Yrs!
Thermal Efficiency, HHV (%)
40
Two Units of Takasago Power Plant in Japan, J-POWER

39
38
37
36

Designed Efficiency

35

Efficiency Degradation
30

A Coal-fired Plant in Another Country
20
0

20

10

30

40

Operated Period (Years)
資料230

6

Other Means to Decrease CO2 Emissions:Biomass Fuels; & More Efficient Technologies
Fuel Conversion
Coal-fired power plant

Municipal
Waste
Carbonized
Fuel〔Public〕
Municipal Waste

SewageSewage Sludge

Sludge Fuel

〔Industry〕
Waste
Woods

Coal

Wood
Biomass FuelPC
USC

1500℃ class GT

IGCC

IGFC

700℃ class A-USC

Fuel Cell

Gas Turbine

Gas Turbine
BoilerSteam Turbine

Gross：43％(HHV)
Net : 41％(HHV）

BoilerSteam Turbine

Gross：50％
Net : 48％

Gasifier

Gross：51- 53％
Net：46- 48％

Steam
TurbineGasifier

Steam Turbine

Gross：60％ aboveNet：55％ above

資料231* CO2 reduction rate is based on latest USC plant. Thus the reduction rate becomes much higher when using existing plants as a base.

7

CO2 Capture Technologies, Followed by
CCS Which Needs Public Sector Commitment■ Entities: Australia/ J-POWER, IHI, Mitsui

PCF■ Scale: 30MW class■ CO2 captured: 30,000 t-CO2/ year

Oxy-fuel

Australia Callide P/S■ Test Period: 2011 - 2014 (planned)■ Entities: J-POWER/ MHI

PCF■ Gas Flow: 1,750Nm3/h■ CO2 captured: 10 t-CO2/ day

Post-combustion

Coal Gasification
燃焼前回収法微粉炭火力発電
Pre-combustion

J-POWER Matsushima P/S
Chemical Absorption T.E.

■ Test Period: 2007/ 4 - 2009/ 3■ Entities: J-POWER/ NEDO
■ Gas Flow: 1,000Nm3/h■ CO2 captured: about 20 t-CO2/ day■ Test Period: 2008/ 11 - 2010/ 3

Ｊパワー・若松研究所
EAGLE試験装置
J-POWER Wakamatsu R.I.
EAGLE Pilot Plant

資料232

8

Transfer & Dissemination of Clean Coal
Technologies (CCTs) Make Global CO2Emissions Curtailed

資料233

9

Efficiency Increase of Coal-fired
Power Contributes to Both…

Security of Energy&
Global Environment
資料234

10

Thank you for yourattention

資料235

Development and Application of USC
Technology for Coal-fired Power
Generation in China

Zhang Xiaolu
Vice President
China Power Investment Corporation
October 2010
資料236

Content
1. Current USC development and applicationin China
2. Technical properties of typical USC units in
China
3. Trend in USC technology development in
China

資料237

1. Current USC development and applicationin China

資料238

 Required by the technological development and progressof China’s power industry, the former State Power
Corporation of China initiated researches on USC applicationand development in 2000, which was officially listed in thenational science and technology research program in 2002.
 A team comprised of Chinese manufacturers, power
generation companies, engineering and research institutes
conducted specific researches on five key areas, including
USC technology selection, key boiler technologies, key
turbine technologies, flue gas purification technologies andpower station design and operation technologies.

資料239

 On that basis, it was determined that China would
develop 1000MW and 600MW units with the steam
parameter of 25-28MPa/600℃/600℃.
 Guided by the results from national USC technology
researches and through international technologicalintroduction and cooperation, the first unit of YuhuanPower Plant of Huaneng Group and Kanshan Power Plant
of CPI Group, which are the demonstration projects for
China’s 1000MW and 600MW USC units, successfullycommenced commercial operation in November 2006 andOctober 2007 respectively.

資料240

 Driven by the increasing power demand and policies
on energy conservation and emission reduction, USC
power generation technology was rapidly promoted in
China.
By the end of 2009, nineteen 1000MW USC units had
been put into operation in China with sixty eight units
under construction, and twenty 600MW USC units put
into operation with fifty units under construction. Ordered
USC units had accumulated to the capacity of 200GW.
As the priority option for Chinese power generationenterprises to develop coal-fired power stations, 1000MW
and 600MW USC units have become leading units in the
newly built capacity in China’s thermal power industry.
資料241

2. Technical properties of typical USC units
in China

資料242

2.1 Design and operation performance test of 1000MW
units of Huaneng Yuhuan Power Plant

資料243

 The 4×1000MW USC coal-fired units of Huaneng
Yuhuan Power Plant features a single reheat, tower type HG2953/27.46-YM1 boiler and single reheat, monoaxial, 4casing 4-flow and condensing N1000-26.25/600 /600 (TC4F)
turbine.
 As a demonstration project for 1000MW USC unit
localization in China, the 4 units of Huaneng Yuhuan Power
Plant were successively put into commercial operation from
November 2006 to November 2007. Results of unit
performance test indicated boiler efficiency and service
power rate all superior to design values and THA and net
coal consumption rate both reached design value.
資料244

Main design parameters and performance test results of
1000MW units of Huaneng Yuhuan Power Plant
No.

Item

Unit

DesignUnit 1

Unit 2

Unit 3

Unit 4value
1

Boiler efficiency

%

93.65

93.88

93.76

93.88

93.89

2

BRL

t/h

2807

2786

2746

2747

2750

3

THA

kJ/kWh7316

7295.87314.97290.97313.6

4

TRL

MW

1000

1001.71000.51001.01000.75

Gross coal consumption rate

g/kWh

269.2

266.4

268.7

268.3

270.9

6

Service power rate

%

4.76

4.45

4.33

4.08

4.42

7

Net coal consumption rate

g/kWh

282.6

278.8

280.6

279.7

283.4

8

Net thermal efficiency

%

43.47

44.06

43.78

43.92

43.35

資料245

2.2 Design and operation performance test of 1000MW
units of CPI Dacaojing Power Plant

資料246

 The 2×1000MW USC coal-fired units of CPI
Dacaojing Power Plant features a single reheat, towertype SG-2956/27.46-M534 boiler and single reheat,monoaxial, 4-casing 4-flow and condensing N100026.25/600 /600 (TC4F) turbine.
 Performance test of the two units was completed in
March and June 2010 respectively, indicating boiler
efficiency, THA, service power rate and net coalconsumption rate all superior to design values.

資料247

Main design parameters and performance test results of
1000MW units of CPI Dacaojing Power Plant
No.

Item

Unit

DesignUnit 1

Unit 2

value
1.

Boiler efficiency

%

93.72

94.23

94.45

2.

BMCR

t/h

2956

2985

2967

3.

THA

kJ/kWh

7306

7301

7303

4.

TRL

MW

1000

1027

1031

5.

Gross coal consumption rate

g/kWh

274

267.4

266.9

6.

Service power rate

%

5.3

3.77

3.92

7.

Net coal consumption rate

g/kWh

289

278

278

8.

Net thermal efficiency

%

42.51

44.19

44.19

資料248

2.3 Design and operation performance test of 600MW
units of CPI Kanshan Power Plant

資料249

 The 2×600MW USC coal-fired units of CPI
Kanshan Power Plant features a single reheat, twopass(п type) HG-1792/26.15-YM1 boiler and thesingle reheat, monoaxial, 2-casing 2-flow andcondensing CLN600-24.2/600 /600 turbine.
 Performance test of the two units was completed inJuly 2008, indicating boiler efficiency, THA, service
power rate and net coal consumption rate all reaching
the guarantee values.

資料250

Main design parameters and performance test resultsof 600MW units of CPI Kanshan Power Plant.
No.

Item

Unit

DesignUnit 1

Unit 2

value
1

Boiler efficiency

%

93.53

93.60

93.54

2

BMCR

t/h

1792

1860

1840

3

THA

kJ/kWh

7424

7421

7423

4

TRL

MW

600

601

614

5

Gross coal consumption rate

g/kWh

276.4

273.7

273.5

6

Service power rate

%

6.5

4.75

4.61

7

Net coal consumption rate

g/kWh

295.6

287.3

284.6

8

Net thermal efficiency

%

41.56

42.76

43.16

資料251

3. Trend in USC technology development
in China

資料252

 As the world is strengthening its efforts in energy
conservation and emission reduction and the Chinese
economy and power industry develop further, USC power
generation technology will be more widely applied in China.
In the next 10 years, USC technology will play a leadingrole in China’s coal-fired power generation industry. Apartfrom co-generation units, all new condensing coal-fired
units will adopt USC technology.
 It is expected that in 2020, installed capacity of
China’s USC units will exceed 500GM, accounting forover 50% of the total installed capacity of all coal-fired
units. The average net coal consumption rate in China has
been reduced from 380g/KWh in 2003 to 342g/KWh in
2009.
資料253

 As more USC units are built and sub-critical thermal
units are decommissioned, it is expected that in 2020,
the average net coal consumption rate in China will befurther reduced to approach 310g/KWh, which is on theleading level in the world.
 In July this year, the National Energy Administration(NEA) of China announced to set up the 700℃ USC
Coal-fired Power Generation Technology Innovation
Union and launched related R&D projects. It is aimed tomake united efforts with the international community todevelop cleaner, more efficient, economic and reliablecoal-fired power generation technologies, making greater
contributions to realizing low-carbon and sustainable
development.
資料254

Development and Application of USC
Technology for Coal-fired Power Generationin China
By Zhang Xiaolu
Vice President of China Power Investment Corporation
With the continuous rapid development of Chinese power industry
and the ever higher standard of environmental protection in this century,
USC power generation technology has realized successful localization andextensive application in China, leading China’s coal-fired power generationindustry quickly into the age of USC technology.
I. Current USC development and application in China
Required by the technological development and progress of China’s
power industry, the former State Power Corporation of China initiatedresearches on USC application and development in 2000, which was
officially listed in the national science and technology research program in
2002.
A team comprised of Chinese manufacturers, power generationcompanies, engineering and research institutes conducted specificresearches on five key areas, including USC technology selection, key
boiler technologies, key turbine technologies, flue gas purification
technologies and power station design and operation technologies. On
that basis, it was determined that China would develop 1000MW and
600MW units with the steam parameter of 25-28MPa/600℃/600℃(generation efficiency≥44.63% and gross coal consumption rate
≤275g/kWh).
Guided by the results from national USC technology researches andthrough international technological introduction and cooperation, the firstunit of Yuhuan Power Plant of Huaneng Group and Kanshan Power Plant
of CPI Group, which are the demonstration projects for China’s 1000MW

資料255

and 600MW USC units, successfully commenced commercial operation in
November 2006 and October 2007 respectively.
Driven by the increasing power demand and policies on energy
conservation and emission reduction, USC power generation technology
was rapidly promoted in China. By the end of 2009, nineteen 1000MW
USC units had been put into operation in China with sixty eight units underconstruction, and twenty 600MW USC units put into operation with fifty
units under construction. Ordered USC units had accumulated to thecapacity of 200GW. As the priority option for Chinese power generationenterprises to develop coal-fired power stations, 1000MW and 6 00MW
USC units have become leading units in the newly built capacity in China’s
thermal power industry.
II. Technical properties of typical USC units in China
1. Design and operation performance test of 1000MW units of
Huaneng Yuhuan Power Plant

Figure 1. Huaneng Yuhuan Power Plant

The 4×1000MW USC coal-fired units of Huaneng Yuhuan Power
Plant (Fig.1) features a single reheat, tower type HG-2953/27.46-YM1
boiler and single reheat, monoaxial, 4-casing 4-flow and condensing

資料256

N1000-26.25/600 /600 (TC4F) turbine. As a demonstration project for
1000MW USC unit localization in China, the 4 units of Huaneng YuhuanPower Plant were successively put into commercial operation from
November 2006 to November 2007. Results of unit performance test
indicated boiler efficiency and service power rate all superior to design
values. Except for Unit 4, THA and net coal consumption rate bothreached design value(Table 1).
Table 1: Main design parameters and performance test results of 1000MW
units of Huaneng Yuhuan Power Plant
No.

Item

Unit

DesignUnit 1

Unit 2

Unit 3

Unit 4value
1

Boiler efficiency

%

93.65

93.88

93.76

93.88

93.89

2

BRL

t/h

2807

2786

2746

2747

2750

3

THA

kJ/kWh7316

7295.87314.97290.97313.6

4

TRL

MW

1000

1001.71000.51001.01000.75

Gross coal consumption rate

g/kWh

269.2

266.4

268.7

268.3

270.9

6

Service power rate

%

4.76

4.45

4.33

4.08

4.42

7

Net coal consumption rate

g/kWh

282.6

278.8

280.6

279.7

283.4

8

Net thermal efficiency

%

43.47

44.06

43.78

43.92

43.35

2. Design and operation performance test of 1000MW units of CPI
Dacaojing Power Plant

資料257

Figure 2. CPI Dacaojing Power Plant
The 2×1000MW USC coal-fired units of CPI Dacaojing Power Plant(Fig. 2) features a single reheat, tower type SG-2956/27.46-M534 boiler
and single reheat, monoaxial, 4-casing 4-flow and condensing
N1000-26.25/600 /600 (TC4F) turbine. Performance test of the two units
was completed in March and June 2010 respectively, indicating boiler
efficiency, THA, service power rate and net coal consumption rate allsuperior to design values. (Table 2)
Table 2: Main design parameters and performance test results of 1000MW
units of CPI Dacaojing Power Plant
No.

Item

Unit

DesignUnit 1

Unit 2

value
1.

Boiler efficiency

%

93.72

94.23

94.45

2.

BMCR

t/h

2956

2985

2967

3.

THA

kJ/kWh

7306

7301

7303

4.

TRL

MW

1000

1027

1031

5.

Gross coal consumption rate

g/kWh

274

267.4

266.9

6.

Service power rate

%

5.3

3.77

3.92

7.

Net coal consumption rate

g/kWh

289

278

278

8.

Net thermal efficiency

%

42.51

44.19

44.19

資料258

3. Design and operation performance test of 600MW units of CPI Kanshan
Power Plant

Figure 3. CPI Kanshan Power Plant
The 2×600MW USC coal-fired units of CPI Kanshan Power Plant (Fig.
3) features a single reheat, two pass(п type) HG-1792/26.15-YM1 boiler
and the single reheat, monoaxial, 2-casing 2-flow and condensing
CLN600-24.2/600 /600 turbine. Performance test of the two units wascompleted in July 2008, indicating boiler efficiency, THA, service powerrate and net coal consumption rate all reaching the guarantee
values(Table 3).
Table 3: Main design parameters and performance test results of 600MW
units of CPI Kanshan Power Plant
No.

Item

Unit

DesignUnit 1

Unit 2

value
1

Boiler efficiency

%

93.53

93.60

93.54

2

BMCR

t/h

1792

1860

1840

3

THA

kJ/kWh

7424

7421

7423

4

TRL

MW

600

601

614

5

Gross coal consumption rate

g/kWh

276.4

273.7

273.5

6

Service power rate

%

6.5

4.75

4.61

7

Net coal consumption rate

g/kWh

295.6

287.3

284.6

8

Net thermal efficiency

%

41.56

42.76

43.16

資料259

III. Trend in USC technology development in China
As the world is strengthening its efforts in energy conservation andemission reduction and the Chinese economy and power industry develop
further, USC power generation technology will be more widely applied in
China. In the next 10 years, USC technology will play a leading role in
China’s coal-fired power generation industry. Apart from co-generation
units, all new condensing coal-fired units will adopt USC technology. It is
expected that in 2020, installed capacity of China’s USC units will exceed
500GM, accounting for over 50% of the total installed capacity of allcoal-fired units. The average net coal consumption rate in China has been
reduced from 380g/KWh in 2003 to 342g/KWh in 2009. As more USC units
are built and sub-critical thermal units are decommissioned, it is expectedthat in 2020, the average net coal consumption rate in China will be further
reduced to approach 310g/KWh, which is on the leading level in the world.
In July this year, the National Energy Administration (NEA) of China
announced to set up the℃700
USC Coal-fired Power Generation
Technology Innovation Union and launched related R&D projects. It isaimed to make united efforts with the international community to develop
cleaner, more efficient, economic and reliable coal-fired power generation
technologies, making greater contributions to realizing low-carbon andsustainable development.

資料260

Current Status of
USC Development in Korea
資料261

Contents

KOSEP Introduction
Why USC ?
Development Trends
Design Features
Operation Problems
Conclusions

資料262
2

KOSEP Introduction
KOSEP was spun off from KEPCO in 2001 as part of the government’s restructuring plan.
Backed by solid fundamentals for the half hundred years since 1961, KOSEP is stepping
toward for leaping to the Global Power Leader in the future.
Restructuring of Electricity Industry(Separation of Generation Sector)

1915
1943 1946
Kyungsung Electric Co.

1961
Korea
Electric
Co.

Chosun Electric Co.
Namsun Electric Co.

Consolidated into
one Company

1982

Korea
Electric
Power
Corporation(KEPCO)

Government Owned Corporation(Generation, Transmission & Distribution)

資料263
3

2001

KEPCO
KOSEP

4 Other
Thermal Power
Companies
Korea
Hydro-Nuclear
Power Co.

KOSEP Introduction – Overview
Overview of electricity industry in Korea and the position of KOSEPKEPCOGenerators

KOSEP

Market Operator
KEPCO as
System Operator

KOMIPOTransmission
Distribution

KPX
KOWECOKEWESPO

KOSPO

PPA
KHNP

IPPs

• IPPs (Independent Power Producers)• PPA (Power Purchase Agreement)
資料264
4

ConsumerCompany Profile

CEO
Do-Soo, Jang
Headquarter
411 Yongdong-daero Gangnam-gu
Seoul
Name

Employees

Korea South East Power Co., Ltd.

1,986 Persons

Foundation Date

Industry

April 2, 2001

Power Generation
資料265
5

KOSEP Strategy
With a corporate philosophy, KOSEP continues to upgrade processes and improve operations tosecure a competitive advantage to become a Global Power Leader in the 21st century.
Corporate Philosophy“Respect for human beings,
Preservation of the natural environment,
Contribution to the community”

Vision“Global Power Leader”

Management Goals- Ensure a stable supply of low-cost, quality electricity- Maximization of corporate value

Management Policy

Faithful to thebasic ones

Build up thefundamental forcontinuous
growth資料266
6

Develop reliablecorporate cultureOrganization & Employees
As a leading player in the Korean power industry, KOSEP has a well-structured
organization for versatile employees

Power
GenerationDiv• Power Generation Dept.
• Construction Dept.

CEOThe Personnel of KOSEP

Support &Mgmt
Div• Planning Dept.
• General Affairs Dept.

Innovation&New Biz
OfficeExecutives

Employees

Etc

Total

4

1,798

184

1,986

Power Plants• Samcheonpo Thermal• Yeongheung Thermal• Yeongdong Thermal• Yeosu Thermal• Bundang Combined Cycle• Muju Pumped Storage• Yaecheon Pumped Storage(Under construction)
資料267
7

KOSEP - Facilities
KOSEP is the largest Genco has base-load capacity 6,580 MW and has the attractive site among
the thermal Gencos in Korea.
Location of Power Generation Facilities

Yeongdong

Bundang
Yeongheung

Yecheon P/S(Construction)
Muju

Facilities in Operation

Metropolitan area

Location

Major industrial/chemical complex

Samcheonpo“Fuel Type”

Capacity (MW)6

Bituminous

3,240

Yeongheung

4

Bituminous

3,340

Bundang

10

LNG

900

Yeosu

2

Oil

529

Yeongdong2

Anthracite

325

Muju

2

Renewable
Samcheonpo
Yeosu

Total
資料268
8

“Operation Units”

PumpedStorage(P/S)

600
10

8,944

KOSEP Introduction
Why USC ?
Development Trends
Design Features
Operation Problems
Conclusions

資料269
9

Why USC ?

Governmental
Strategy
New Growth Modelfor Korea

Fuel(Coal)
Consumption

Environmental
EffectParticular Situation toImport all the coal

CO2 Emission
Carbon-tax

資料270
10

Governmental Strategy
Green Growth, The New Growth Model for Korea‘Low-Carbon, Green Growth’ presented as the national vision
by President Lee, Myeong-Bak during his address on August 15, 2008

資料271
11

Advanced Steam Condition in Thermal Power Plant
 Advanced steam temperature and pressure parameters for USC can deliver the mosteconomical way to improve plant efficiency and operating flexibility, achieve fuel costsaving, and reduce CO2 emissions for each kWh of electricity generated
 USC technology is most effective for thermal power plant design to consider the carbon
tax

Break even USC PC total Plant Cost , $/KW

1700
Without
Carbon-tax
탄소세
없는
경우

1600

$7/ton CO2$14/ton CO2$27/ton CO2

1500
1400
1300
1200
1100
1000
900
0.5

1

1.5
2
Levelized Coal Cost, $/mmBtu

2.5

330years , 80% Capacity Factor Sub Critical (Plant cost of $1019/KW, Heat rate of2305 Kcal/KWh, 37%)USC (Heat rate of 1900 Kcal/KWh, 45%)(EPRI)
資料272
12

Fuel(Coal) Consumption
Korea imports all the coal from abroad. In recently, low calorie coal imported fromIndonesia is increasing for energy price rise

Bituminous Coal Prices Trend (‘08~‘10, U$/ton)Coal’s Import Structure of Korea (‘08)

250
Others10%200Australia
40%

Indonesia
26%

150

China
17%

100

Canada7%50[ 1000 Ton ]Sep/10

Jul/10

May/10Mar/10

Jan/10Nov/09Sep/09Jul/09

May/09Mar/09Jan/09Nov/08Sep/08Jul/08May/08Mar/08Jan/08

0

資料273
13

Country
Imports

Australia Indonesia
36,36923,685

China

CanadaOthers

14,837

6,521

9,057

Enlarging Uses of Low Calorie Coal
In preparation for coal price rise and competition, the technology development to operate
power plant by low calorie coal is expending

Average Heating Value(kcal/kg)
6,200
6,100
6,000
5,900
5,800
2007

5,700

2008

5,600

2009

5,500
5,400
5,300
5,200

Samchunpo
삼천포Boryung보령Yeounghung
영흥
資料274
14

Taean
태안

Hadong하동

Dangjin당진

KOSEP Introduction
Why USC ?
Development Trends
Design Features
Operation Problems
Conclusions

資料275
15

History of Steam Condition Change in Korea
KOSEP has been led UCS technologies by improving steam condition of Yeounghung 3,4
unit at first and plans to lead Korea power industry steadily through the construction ofYeounghung 7,8 unit
OTSC

STM Condition
265 × 610 / 621

OTUSC

OTUSC

Phase 1

Phase 2
1,000MW
Dangjin 9,10

800MW
Yeonghung1,2

246 × 566 / 593
246 × 566 / 566
246 × 538 / 538
169 × 538 / 538
169 × 538 / 538
127 × 538 / 538

500MW
yeonghung3~4(870) Dangjin5~8
Taean 7,8 Boryung7.8 Hadong7,8500MW, 560MW
Boryung#1,2, Samcheonpo 1~4

500MW
Boryung#3~6 Taean #1~6,
Dangjin #1~4 Hadong #1~6

200MW
Yeondong#2
60MW, 75MW Pusan
1,2/Kunsan

88 × 510 / 510

200MW
Seochun #1,2
125MW
Yeongdong#1

60S

70S

StandardizationStandardization
1,000MW
Step 1
Step 2Standardization
(20)
(10)
800MW
Standardization
Step 1

80S

90S

00S

10S

* OTSC : Once-through Super Critical* OTUSC : Once-Through Ultra Super Critical
資料276
16

Target On
Efficiency
45%
43.5%
43.0%
41.0%

Steam Condition
Steam conditions at new plant were reviewed by each maker after considering materials
and heat rate. Then we provisionally decided 264kg/cm2/ 610℃/ 621℃
[Unit : kcal/kWh]Steam Condition

Tandem Compound

Cross Compound

246kg/cm2/ 566℃/ 593℃

1,773 (Base)

1,801(Base)

246kg/cm2/ 610℃/ 610℃

1,744(-1.6%)

1,765(-2.0%)

246kg/cm2/ 621℃/ 621℃

1,728(-2.5%)

1,753(-2.7%)264kg/cm2/ 610℃/ 621℃

1,722(-2.9%)

1,747(-3.0%)281kg/cm2/ 610℃/ 610℃

1,728(-2.5%)

1,751(-2.8%)

281kg/cm2/ 621℃/ 621℃

1,717(-3.2%)

1,741(-3.3%)

Condition

GE

MHI

Hitachi

Siemens

0.5%

0.7%

0.7%

-

Steam Temperature 28℃(50℉) ↑

0.7%

0.5%

0.5%

0.7%

Reheat Stage(1→2) ↑

2.0%

1.6%

1.6%

1.6%

Main Steam Pressure
35kg/cm2(500psig)↑

資料277
17

Materials
Ferritic steels are preferred because of lower coefficient of thermal expansion and higher
thermal conductivity compared to austenitic steels. So we are focusing on developing theequivalent ferritic steel capable of operating at metal temperature up to 600 ℃
Case I
246㎏/㎠
566/593℃

Case 2246㎏/㎠
610/610℃

Case 3
246㎏/㎠
621/621℃

Case4
264㎏/㎠
610/6210℃

Case 5281㎏/㎠
610/610℃

Bottom

2.25Cr-1Mo

2.25Cr-1Mo
2.25Cr-WVNb

9Cr-0.5Mo-1.8WV
Nb
2.25Cr-WVNb

9Cr-1MoVNb
2.25Cr-WVNb

2.25Cr-WVNb
9Cr-1MoVNb

Top

2.25Cr-1Mo

Item

B
O
I
L
E
R

T
U
R
B
I
N
E

Water
Wall

Case 6281㎏/㎠
621/621℃

12Cr-MoWVNb
9Cr-0.5Mo-1.8WV 9Cr-0.5Mo-1.8WV 9Cr-0.5Mo-1.8WV 9Cr-0.5Mo-1.8WV 12Cr-WCoNiVNb
Nb
Nb
Nb
Nb
12Cr-MoWVNb
12Cr-MoWVNb
12Cr-MoWVNb
12Cr-MoWVNb

Final Super
Heater

18Cr-8Ni-CuNbN

18Cr-9Ni-CuNbN
18Cr-10NiNb

25Cr-20NiNbN
20Cr-25NiMoNb
Superalloy

25Cr-20NiNbN
20Cr-25NiMoNb
Superalloy

25Cr-20NiNbN
20Cr-25NiMoNb

Superalloy

Final Reheater

18Cr-8Ni-CuNbN

18Cr-9Ni-CuNbN
18Cr-10NiNb

25Cr-20NiNbN
20Cr-25NiMoNb
Superalloy

25Cr-20NiNbN
20Cr-25NiMoNb
Superalloy

25Cr-20NiNbN
20Cr-25NiMoNb

Superalloy

Rotor

12Cr

12Cr

Superalloy

12CrMoWVNbN
Superalloy

12CrMoWVNbN

Superalloy

Inner Casing

12Cr

12Cr

12CrW
316H

12CrW
316H

12CrW

Superalloy
316H

Outer Casing

2.25Cr-1Mo

12Cr

12CrW
316H

12CrW
316H

12CrW

12Cr-0.4Mo-2W
12CrW
316H

資料278
18

Carbon-Tax Saving
Analysis about the cost & benefit of greenhouse gas reduction including the carbon tax is
proceeding in several different ways.
And respond to the environment regulations actively. We reserve available space for CO2
reduction equipment for retrofit in the future .
Based on carbon tax($5/ton), The reduction of the cost to consider carbon taxes is asfollow[Unit : 10,000 Won]

Turbine Arrangement

Case1
246㎏/㎠
566/593℃

Case2
246㎏/㎠
610/610℃

Case3
246㎏/㎠
621/621℃

Case4
264㎏/㎠
610/621℃

Case5
281㎏/㎠
610/610℃

Case7
281㎏/㎠
621/621℃

Tandem CompoundBase▽12,721▽19,814▽22,516▽19,814▽24,655

Cross Compound△12,271▽3,490▽8,781▽11,483▽9,682▽14,072

資料279
19

Environmental Facilities
We have installed most advanced environment facilities to aim for the world Best and themost environment-friendly power plant

Item

YeongHung#1,2

YeongHung#3,4

YeongHung#5~8

DangJin#9,10

Hekinan#1~3

Hekinan#4,5

Tachibanawan #1,2

NOx
(ppm)

≤ 55
(≥72%)≤ 15(≥90%)≤ 12(≥92%)≤ 50(≥72%)≤ 30(≥80%)≤ 15(≥90%)≤ 45(≥90%)

SOx
(ppm)

≤ 25
(≥95%)≤ 20(≥97%)≤ 15(≥97%)≤ 40(≥96%)≤ 28(≥96%)≤ 25(≥97%)≤ 50(≥94%)

Dust(mg/S㎥)

≤ 20

≤5

≤5

≤5

≤5

≤5

≤ 10

資料280
20

Coal Blending
In case of new thermal power plant, we plan to co-fire with low calorie coal more than 50%
considering impact of boiler materials and supply condition of low calorie coal.
Moreover, we are developing new auxiliary operation systems such as coal blending
technology, multi media soot blower, expanding low calorie coal with strong Slagging
Power Planet

DesignOperation

500MW, 800MW

Bit.

Blending Low Calorie Coal(30%)※ Additional soot blowers are installed because of slagging/fouling caused by low calorie
coal blending

Power Planet

Coal TypeMax. Sub. Bit.
Blending Ratio

Young Hung #3,4

Bit + Sub b

50%

Dang Jin #5,6

Bit + Sub b

30%

Samchunpo #5,6

Bit + Sub b

70%

資料281
21

KOSEP Introduction
Why USC ?
Development Trends
Design Features
Operation Problems
Conclusions

資料282
22

Design Features – Steam Generator
 Two Pass type considering
heat transfer and cost
efficiency

 Metal temperature
reduction using orifice RH steam temp control bygas damper Furnace design preventing
slagging under wide rangecoal Flame stabilization Low Nox
burner for low oxygen
atmosphere of 2stage OFA

 Spiral type water wall tube tominimize temp. deviation

資料283
23

Design Features - Turbine
 Brush seal
 Longer last blade bucket Integral cover bucket Advanced vortex stage

 Large radius root deflector
 Turbine cooling system

資料284
24

Design Features – Bypass System

 Improvement of Loadchange characteristics
through applying 3 stage
feederwater priority control

 RH Bypass system for over
600℃ temperature

CRH SV Water wall recirculation
system considering start-up
and cost saving

HPBP HP/LP Bypass system toprevent BLR tubes fromoverheating and TBN
internals from the damage
by solid particles

HP

IP

Cond

RH

SH

LP TBN

HRH SV
LPBP
LT

COP

W/W

DEA

BCP

HP HTR

資料285
25

BFP

LP HTRGEN

KOSEP Introduction
Why USC ?
Development Trends
Design Features
Operation Problems
Conclusions

資料286
26

Boiler Tube Damage○ S/H, R/H Tube Damage
Main Causes- Improper material selection(A213T91)- Tube overheating by inside scale(round tube)- Welding problem at shop or field(especially different material) and Deterioration• Counter measures- upgrade tube material at Final S/H and R/H- Install Thermo Couple to monitor overheating- Minimize welding point of different material○ BLR Water Wall Tube

DamageCause : Due to large Clinker drop
Solution : Install water cannon○ BLR ECO Tube Damage
Due to ash cutting with low-quality coal
資料287
27

S/H Steam Temperature Control[Yaw System]

Main Steam Temp Deviation (Left, Right)
Left Steam Temp(15~20 ℃) > Right Steam Temp

[Windbox Tilt]

One pass Boiler < Two pass Boiler
Full Load < Partial Load
Cause : Feature of Tangential Corner Firing(Swirl)
Solution : Install Yawing System + W/B Tilt

[Before]
資料288
28

28

[After]Boiler Tube Design Mistake

BLR trips due to Furnace Pr. High
Slope tube Bundle vs. flat tube bundle
Generate and build up slag on the slope
Slag falls to seal trough → Furnace pr fluctuation
Furnace pr. Hi-Hi Trip
Cause : Design Error of Tube Bundle shape
Solution : Install more Soot blowers

資料289
29

KOSEP Introduction
Why USC ?
Development Trends
Design Features
Operation Problems
Conclusions

資料290
30

Conclusions

 Korea’s annual energy consumption is expected to increase 2~3% until 2020 by the
improvement of living standard
 To meet these energy demands, it's necessary to build coal fired power plant(largescale and USC) along with developing nuclear / renewable energy source The main reason of adoption USC facility is to meet the plant market requirement withconsidering governmental strategy, environmental effect, economic fuel use andthermal efficiency
 So, we are developing USC technology to expand low calorie coal use and to keep low
electricity-generation cost. And we will see the visible results as the construction of
Yeonghung 5,6 unit and Dangjin 9,10 unit after 2015

資料291
31

Thank You !!!

資料292
32

New Developments in Clean Coal and CO2 Reduction Technologies
APEC Clean Fossil Energy Technical and Policy Seminar 2010

CO2 Reduction by Development of High-Efficient
Coal-Fired Power Generation in Japan

27 October, 2010
Hilton Fukuoka Sea Hawk

Kazuhiro Izaki

General Manager
Thermal Power Department
Thermal Power Generation Division
Kyushu ElectricPower Co., INC
資料293～ Enlighten Our Future ～Transition of power generation by fuel (Nationwide)
10,905 GWh(2019)
9,551 GWh(2009)(GWh)

12,000

Renewable Energy

1.6%

1.1%

8.8%

10,000

Hydro
Expansion of overseas
coal power generation

8,000

Commercialization of nuclear
power generation

4,000

LNG

2,000

Coal

Oil and Others
0
1952

1958

1966

▼
▼
1973/1978 Oil crisis

1974

29.2%

41.0%

Nuclear

Expansion of LNG
power generation

6,000

8.0%

1982

29.4%

24.7%
7.6%

1990

1998

2006

22.4%

20.8%
5.3%

2014

【source】 Electricity supply plan outline (Agency for
Natural Resources and Energy and others)
資料294～ Enlighten Our Future ～2

Development of high efficiency in coal-fired power plants
Development of the integrated
coal gasification combined cycle(IGCC) and A-USC technology

Introduction of super-criticalpressure to coal-fired power
generation

J-Power Isogo #2 (600MW)
25MPa, 600/620°C

Designedthermalefficiency
(LHV)

46%

Introduction of ultra
supercritical technology
Oil-fired plants adopted
supercritical pressure earlier.
TEPCO Yokosuka #1 (265MW)
16.6MPa, 566/566°C

Chubu EPCO Hekinan #3 (700MW)
24.1MPa, 538/593°C
J-Power Matsushima #1 (500MW)
24.1MPa, 538/538°C

44%
Chugoku EPCO Misumi #1 (1,000MW)
24.5MPa, 600/600°C
42%

40%

Introduction of the latest
technology from EU and US(Adoption of reheat cycle)

Use of domestic coal

Use of overseas coal
38%

Supercritical

Ultra Supercritical
Advanced Ultra 36%
Supercritical

Kyushu EPCO Karita #1 (75MW)
10MPa, 538/538°C

Oil crisis（1973/1978）
Ban on the construction of new oil-fired plants (IEA)

1950

1960

1970

1980

【source】 The Thermal and Nuclear Power, Oct 資料295
2006, etc.
～ Enlighten Our Future ～

1990

2000

2010～
3

Technology development in the thermal power generation field
Combined Cycle Power Generation
Coal gasification
C/C: Non-commercialized
technology%: Gross generating
efficiency (LHV)

1200°C class
Nakoso IGCC
demo plant
48%

IGCC
1300°C class49 – 51%

IGCC
1500°C class
51% -

850°C classpressurized fluidized (Direct combustion of coal)
bed C/C
43 – 44%

Coal fluidized bed
C/C

Coal Combined Cycle Power Generation

LNG C/C

Subcritical
400°C class~ 28%

1100°C class
Combined Cycle
48 – 49%

Supercritical
500°C class40 – 42%

1400°C class
Combined Cycle
53 – 54%

1500°C class
Combined Cycle
55 – 59%

Ultra Supercritical Improvement in steam condiitons
600°C class42 – 44%

1700°C class
Combined Cycle
62%

Advanced Ultra
Supercritical
700°C class
48% ~Conventional Power Generation
資料296～ Enlighten Our Future ～4

Clean coal technology development status
1996
～
2001

2002
～
2006

2007

IGCC
demonstration
test

Air-Blown

Oxygen-Blown

2010

2011

2012

2013

2014

2015

Facility design, construction
and installation

2016

2017

2018

2019

Test andevaluation

Design and construction

Nakoso

IGCC

2009

System design and element
development

A-USC technology
development
project

EAGLE(Wakamatsu)

2008

Extension Extend the demo test to 2012

Design and construction
Demonstration test

Development of highefficiency
CO2
separationand capture

Design and construction
Oosaki

Demonstration
test

Oxygen-Blown

CO2 separation and Capture
Establishment of base technologies for CCS (2015)▼
Reservoir evaluation and demonstration

CCS
Drilling of test well

Commercial operation (2020～)

資料297～ Enlighten Our Future ～5Efforts toward practical use of USC and higher efficiency (A-USC)
New materials were developed based on SC technology, and the actual USC plant began
operations in 1993.
To improve steam conditions and promote higher efficiency, the A-USC development projectis underway, setting the target net efficiency at 48 – 50% (LHV).
For its practical use, new heat resistance materials for the boiler and turbine with 700℃
class steam condition are presently being developed.
Pressure (Mpa)
SH temp. (°C)
RH temp. (°C)

25
540
560

Water wall

USC
25
566
566

25
600
600

A-USC
30
650
650

Improved low
alloy steel

Low alloy steel

Hot area of heattransfer pipe

2.25 - 9Cr

Header of main
steam pipe

30-35
700-720700-750

Ni base, etc.
(Under dev)

SUS

Ni base, etc.
(Under dev)

9 - 12Cr

105 Rupture Strength (MPa)SC

Conventional
materials

Ni base alloy

Temperature (deg C)

25MPa 600℃

35MPa 700℃
Higher efficiency

Boiler
ボイラ

HP

IP

LP

Boilerボイラ

VHP HP

IP

LP

Steam Turbine

One-step reheating

USC net generating efficiency 43% (LHV)～ Enlighten Our Future ～Two-step reheating
資料298

A-USC net generating efficiency 48 - 50% (LHV)
6

Development of advanced coal-fired power generation technology(Kyushu EPCO)

Combined cycle generation system

Gross generating efficiency (LHV) (%)

(%)

A-USC
(700°C class)
48% or more

60

50

40

30

20

Reihoku #2 (700MW)・ 593/593°C
・ 24.1MPa

43.9％

41.7％

43.5%

35％

Karita #1 (75M)・ 538/538°C
・ 10MPa

Matsuura #1 (700MW)・ 538/566°C
・ 24.1MPa

Pressured fluidized bed
combustion (PFBC)
Karita-shin #1 (360MW)
・ 566/593°C
・ 24.1MPa
・ 850°C class GT

IGCC commercial
unit(1,500°C class GT)
51% or more
Bird’s eye view of PFBC

Improvement in steam conditions: Actual: Plan10
1951 1953 1955 1957 1987 1989 1991

1997 1999 2001 2003 2005 2007 2009

資料299

～ Enlighten Our Future ～7

Comparison of coal thermal power plant efficiency in Japan with other countries

Gross generating efficiency (LHV) （%）

Thermal power generation in Japan has achieved the world’s highest level of thermal
efficiency.

43
Japan

41
39

GermanySouth Korea

37

United States

35
Australia

33
31

China

India

29
1990

1992

1994

1996

1998

2000

2002

2004

2006

※ Thermal efficiency is the gross generating efficiency based on average efficiencies for coal (lower heating value standard).
【source】 International Comparison of Fossil Power Efficiency and CO2 Intensity 2009 (ECOFYS)
資料300～ Enlighten Our Future ～8Power generation composition by source in major countries
Coal

Oil

World

Gas

Hydro

Nuclear

41.6

5.6（2007）

Others
13.8

20.9

15.6

2.6

1.8

United States

49.0

21.2

19.4

2.9

5.8

1.0 1.9

China

80.9

14.6

2.9

1.2

Japan

27.7

13.9

India

25.8

68.4

South Korea

23.5
4.1

40.1

5.9

8.3

19.3

2.6

6.6

2.1

15.4

1.7
0.9

33.6

0.3

1.8

Germany

49.3

11.6

22.3

3.3

11.7

15.4

5.7

0.9

Australia

76.3

0%

20%

40%

60%

80%

1.8

100%

【source】 IEA Energy Balances of OECD Countries 2009 Edition etc.
資料301

～ Enlighten Our Future ～9

Estimation of CO2 reduction by USC technology
Based on total CO2 emissions from all energy consumed in energy extraction, plant construction, transportation, re-fining,plant operation and maintenance, etc., in addition to fuel burning.

1.1
Facility/Operation

CO2 Emissions Intensity [kg-CO2/kWh]

1.0
0.9

Combustion

CO2 emissions from developing countries can be reduced byusing Japanese USC technology.

0.8
0.7

About 12% of CO2 and fuel consumption can be reduced.

0.6(Calculated by Kyushu EPCO)

0.5
0.4
0.3
0.2
0.1
0.0

Developing Reihoku 2 Shin Oita 3
nations (USC; 43%)(54%)(38%)

Coal

Solar

Wind

Nuclear Geothermal

Hydro

LNG C/C The value in parentheses shows thermal efficiency (LHV). CO2 emission intensity is assumed by the thermal efficiency of coal-fired
power generation, which prevails in developing countries with 16.6 MPa 566/566°C.
資料302Industry【source】 Report of Central Research Institute of Electric Power～ Enlighten Our Future ～10

Our international effort in reducing CO2
1. Thermal efficiency improvement project, Huang tai coal-fired power plant#7, Shandong Electric Power Company, China
 July 1997 – June 2001: Conducted the performance test at Huang tai #7 (300,000 kW) andanalyzed the result. Subsequently made a proposal on the thermal efficiency improvement.

(Result) Thermal efficiency was improved by 4.4 points. (33.17  37.57%)

2. Participate in APP (Asia-Pacific partnership on clean development and climate) A regional cooperative partnership aiming for appropriate responses to environmental
pollution, energy security and climate change problems in the context of growing energy
demand (Established in July 2005. Seven member countries: Japan, Australia, China, India,
South Korea, USA and Canada) Consists of eight task forces. We have participated in peer review designed to maintain andimprove the thermal efficiency of coal-fired power plants in the “Power Generation andTransmission Task Force”.

3. Consulting service on thermal plant operation improvement plan andresearch in India
 In response to the request from the Indian government, JICA planed the joint project and weare providing the consulting service in cooperation with J-Power and Chugoku EPCO.
 Diagnosed the existing coal-fired power plants and their thermal efficiency in India. Then we
will propose the best improvement plan incorporating our advanced thermal efficiency
improvement technology and promote technology transfer to Indian power plant engineers.
資料303～ Enlighten Our Future ～11Conclusion

Thermal power generation continues to be an important power supply source
both at home and abroad. Coal, in particular, excels in stable procurement
and economy, and is one of the important power generation fuels.
To achieve further reductions of environmental impact from coal-fired thermal
power generation, it is essential to research and develop clean coaltechnology such as IGCC and A-USC for high efficiency and CCS for CO2
separation, capture and underground storage.
In the future, for Asian countries where energy demand is rapidly increasing,Japanese cooperation and support with our world’s leaders in clean coaltechnology is becoming more and more important.

資料304～ Enlighten Our Future ～12Enlighten Our Future
Towards a comfortable and environment-friendly
lifestyle today and for generations to comeThank you for your attention
資料305～ Enlighten Our Future ～12

(6)特別講演 5

資料306

APEC Cl
Clean F
Fossilil E
Energy T
Technical
h i l andd
Policy Seminar 2010
Fukuoka Japan
Fukuoka,
Japan, 27 October 2010

ADB’s Support towards
Efficient CoalCoal-Fired Power
Generation
Jong--Inn Kim
Jong

Lead Professional (Energy)
Regional and Sustainable Development Department
Asian Development Bank
資料307

O tliOutline Use of Coal in AsiaAsia-Pacific ADB’s Involvements in Coal Power

Generation
 ADB’s Policy on Coal
Coal--based Power
Generation
 Recent Projects
 Conclusions

資料308

U off CoalUse
C l ini AsiaAsia
A i -Pacific
P ifi
Coal Demand projected to grow 2.1 % per year
through 2030 – slower rate than 2.4% of total
primaryiEnergy Demand
d
Coal

Oil

Gas

Hydro

Nuclear

NRE

8000• Coal: 38% in 2030
(42% in 2006)

7000
6000
MTOE



5000

• 88 % of incremental
coall demandddby power sector

4000
3000
2000
1000
0
1990

1995

2000

2005

2015

2030

Source: ADB. 2009. Energy Outlook for Asia and the Pacific
資料309

Use of Coal in AsiaAsia-PacificElectricity Generation Mix
Nuclear,
8.7%

Others,1.2%

Nuclear,
14 0%
14.0%

Others,4.1%

Hydro,
12.9%
Hydro,
11.9%
Natural
Gas
Gas,
13.3%

Coal,
52.0%

Coal,
58 1%
58.1%

Natural
Gas,
16 0%
16.0%

Oil, 5.7%

Oil 2.0%Oil,
2 0%6,549 TWh

14,016 TWh

2006

2030

Source: ADB. 2009. Energy Outlook for Asia and the Pacific
資料310

Use of Coal in AsiaAsia-PacificShare of Coal Power Generation
2006,%

2030,%

PRC

80.4

62.9

Japan

27.4

23.4

India

68.3

63.9

Australia 79.2

71.6

Pakistan

0.1

7.1

Korea

40.9

Indonesia

44.1

62.8

Malaysia

25.3

37.0

Viet Nam

17.2

31.3

Thailand

18.0

27.4

Asia--Pacific 58.1
Asia

52.0

W
World
ld

49

47

資料311

38.0

Sources: ADB. 2009. Energy Outlook in
Asia and the Pacific.
IEA 2008 World Energy Outlook
IEA.
& 2009 WEO

Environmental Implications
Coal’s onon-going role underlines the importance ofimproving efficiency of coalcoal-based power plants andminimizing their environmental impacts
 A number of pollutants (e.g. CO2, SOx, NOx,particulates, ash, contaminated water etc) emitted
from coal
coal--based power plants require consideration
 Power generation (using coal) is now responsiblefor 30% of global warming and climate change A range off ttechnologies
h l i hhave bbeen ddeveloped
ld tto
improve the efficiency and reducing the pollutantspollutantsClean Coal Technologies


資料312

ADB
ADB’’s Involvements in Coal
Power Generation
 1972
1972--1995: 21 ($($2,489m),)– Public (19, $2,389m); Private (2, $100m)
 1996
1996--2002: 0
 2003
2003--2009: 7($ 985m)– Public ( 2, $163m);
 Total:Private (5, $885m)

28 ($3,402m)($3 402m)– Public (21, $2,552m); Private (7, $985m)

資料313

ADB’s 2009 Energy Policy Objective:

To help DMCs provide reliable, adequate, andaffordable energy for inclusive growth in a socially,
economicallyi ll andd environmentallyit ll sustainablet i bl WayW Three Pillars– Promoting energy efficiency and renewableenergy– Maximizing access to energy for all– Promoting energy sector reform, capacity
building, and governance
資料314

2009 Energy Policy- CoalCoal-fired Power Generation (I)ADB will selectively support coalcoal-based power
projects if cleaner technologies (such as fluidized
bed combustion
combustion, supercritical and ultraultra-supercriticalboilers, and flue gas desulfurization) are adopted
and adequate mitigation equipment and measures
are incorporated into the project design
As new technologiestechnologies-such as IGCC and CCS
CCS--areshown to be technicallyy feasible and economicallyyviable, ADB will support their deployment in DMCs toincrease their financial viability
ADB will
ill also
l assist
i t DMCs
DMC iin collaborating
ll b
ti
with
ith
developed countries on long
long--term technology
transfer agreements for new and better technologies
under
d d
developmentl
資料315

2009 Energy Policy- CoalCoal-fired Power Generation (II)Some DMCs with smaller size grids that dependon oiloil--based p
power supply
pp y or importspfromneighboring countries may need to install coalcoalbased power plants using subcritical boiler
technology. Such diversification will improve
power system reliability and energy security, andmay be the leastleast-cost option. In the interest of
economical and developmental needs, ADB will
support such basebase--load power plants, if found tobe justified after due diligence
Assistanceiwill
ill also
l beb extended
d d to retrofitting
fi iexisting power plants that need to improve
efficiencyy
資料316

Recent Projects (2009 ~) Visayas BaseBase-Load Power Development

Project (Philippines) Tianjin IGCC Power Plant Project (PRC)
 Carbon Capture and Storage (CCS)

Activities

資料317

Visayas BaseBase-Load Power
Development Project







Approved on 11 Dec 2009
200 MW CFB (two 100 MW units) in Naga City,
Cebu, Philippines$ 20 lloan out off totall project$120m
jcost off $
$486m
86 to
KEPCO Philippines Holdings Inc. with a term of up
to 12 years, including a grace period of up to 2
years without government guarantee
Two 100 MW units are deemed optimal due tosmall grid size and projected demand of the
Visayas grid

資料318

Ti ji IGCC P
TianjinPower Pl
Plant P
Projectj

Approved on 10 Feb 2010



250 MW IGCC in Tianjin Harbor
Ha bo Industrial
Ind st ial park
pa k







$135m loan out of total project cost of $419.6m to
PRC government with 26 years term,
term including 6
years grace period. EXIM Bank of China will onlend
these loan to China Huanengg Groupp and subsequentqonlend to GreenGen Company Ltd.
Ag
grant of $5m will be financed from the ADB’s
Climate Change Fund to mitigate risksFirst IGCC project in PRC in line with “GreenGen”
program (First in Developing Asia as well)
資料319

CCS Activities


Two Technical Assistances for CCS– TA 7286 to PRC for CCS Demonstration – Strategic
A l i and
Analysisd Capacity
C
it Strengthening,
St e the iMay
M 2009,2009 forfo$1.25m– TA 7278 for CCS Demonstration in Developing Countries A AnalysisAn
A l i off Key
K P
Policyli Issues
I
anddB
Barriers,i
M
May 2009
2009,
for $350,000

ADB is a stakeholder in the Carbon Sequestration
Leadership ForumADB is also a foundation member of the Global CCS
I tit t Australia,
Institute,A t li whichhi h hash createdt d a dedicatedd di t d
CCS Fund (Aus $21.5m) under ADB’s Clean Energyg Partnership Facility
Financing

資料320

Conclusions (I)

ADB will selectively support efficient clean coalcoalfiring power projects in DMCs provided that:– A minimum of supercritical technology (not adversely
affect the grid stability)– The project is req
requiredired to impro
improveeooverallerall energ
energy sec
security,rit
reduce power deficits or expands coverage to rural
population or the poor
– There is an ongoing policy dialogue to improve energy
efficiency in the power sector in the particular DMC– Any coalcoal-fired power plant utilizing cleaner technology
must also demonstrate an improvement in net plant
efficiency

資料321

Conclusions (II)For financing subsub--critical technology, the key
considerations are– Grid size
– Capability and experience of operators/sponsors in handlingother more efficient technology
technolog– Country’s development level– Ongoing policy dialogue to improve energy efficiency
efficiency, thecountry should have a plan to gradually move to cleaner
technologies over the next few years



Close monitoring technical advances of clean coaltechnologies (including CCS) for deployment in
DMCs
資料322

Thank you

For More Information
Jong--Inn Kim
Jongjkim@adb.org
jkim@adb.org

資料323

(7)セッション 3

資料324

APEC Clean Fossil Energy Technical and Policy Seminar 2010 @FUKUOKACCT ワークショップ 20100

IGCC with CCS
高効率石炭火力の- Advancedクリーンコールテクノロジー
Technology from Japan to the World Demonstration to Commercial Application

General Manager
IGCC & Gasification
副社長執行役員
福江一郎
Takao Hashimoto
平成22年7月6日

OCT.27 ,2010
資料325

Photo : 250MW IGCC Demonstration© 2010 MITSUBISHIPlant
HEAVY @
INDUSTRIES,
LTD.JapanAllrights reserved.
Nakoso,
250MW
IGCC
実証機

Outline of Air-Blown IGCC Systemdeveloped in Japan

1

Power Block

Gasification / Gas Treatment Island(Equivalent to General NGCC Plant)
Stack
Coal

Gasifier Heat
Exchanger

Gas Treatment

Heat Recovery
Steam Generator

Ambient
Air
Steam Turbine

Pulverizer

RecycledChar

HopperTransformer
Generator

Gas Turbine
Air

Slag
Hopper

N2
Air

ASU

O2

Cooling
Water
Compressor

SystemKey.”
System integration
integration isis thethe ““Key.”
資料326© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

IGCC/Gasification Technology Providers
in the World
Air-Blown
Dry Coal Feed
Membrane Waterwall

2

Oxygen-Blown
Slurry Feed
Refractory

2 Chamber / 2 Stage

Semi-2 Chamber / 2 Stage

1 Chamber / 1 Stage

Conoco-Phillips

GE

SyngasSyngasMembrane Coal
Wall
OxygenReductor

Coal
Slag

Combustor
Slag Hole

Coal
Air

Shell

Slag

MHI Gasifier

Siemens
資料327

2© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

3

Features of Air-Blown IGCC
Realize the Lowest Cost with Various Advantages• Highest Plant Efficiency Because of Air-Blown Gasifier
for IGCC• Flexibility for Variety of Coal Including Brown Coal Becauseof 2-Staged Dry Coal Feed and “Fine” Coal Pulverizing
System• Higher Reliability & Easier Maintainability with
Membrane Waterwall Configuration• Effective Utilization of By-Product like Discharged Molten
Slag, Recovered Sulfur, etc.
• High Plant Efficiency by “G” Type High Temp. GT and High
Reliability from Abundant “Low Calorie Gas Firing” GT
資料328© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

4

Features of Air-Blown IGCC
Air-blown⇒ Lower auxiliary power(Large Capacity ASU units are not necessary)

Dry coal feed ⇒ Lower heat loss than slurry feed

Highest efficiency
Plant Efficiency

Japanese IGCC
technology

USA/EU ‘s IGCC
technology

Gross
Auxiliary
Power
48%

+3%(abs.)
Net+5%(abs.) 45%
43%
42%

MHI
Air-Blown IGCC

O2-Blown
IGCC(Dry Feed)
資料329

O2-Blown
IGCC(Slurry Feed)

USC Boiler© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

5

Features of MHI Gasifier

資料330

5
© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

6“Variety of Coal” Experience

Fuel Ratio (=FC/VM)

3.0

Australian Coal
American Coal
Chinese CoalSouth African Coal
Indonesian CoalJapanese Coal

2.5

2.0

Demo.Plant
ActualNo Needof Flux

May Need Flux

1.5
Demo.Plant
Design1.0

Easy to Gasify
0.5
1,100

1,200

1,300

1,400

1,500

1,600

1,700

Ash Melting Temperature [deg-C]
FC : Fixed Carbon, VM : Volatile Matter
資料331© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

7

IGCC is Advantageous for Lignite
Bituminous

Lignite19m (×1.24)

21m (×1.26)

55m (×1.06)

資料332

Volume
1.9 Times

392m2(×1.56)55m (ベース)(Base)

Φ6.0m(Base)(ベース)

43m (ベース)(Base)(Base)
17m (ベース)

251m2
(ベース)
Base

55m (ベース)(Base)

Gasifier
for M701G(600MW)(Base)
43m (ベース)

Boiler(600MW)(Base)
52m (ベース)

15m (Base)
(ベース)

Φ6.2m
(×1.03)Base© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

8

Advantage in Slag Treatment
100
100

Ash pond
area ratio [%]灰捨て場面積比Gasifier
Combustor[%]

Slag HoleSlag

CameraCamera80

Slag Water
BathSurface

80
80

60
60

40
40

20
20

Slag Water Bath60

00

Unburned
CarbonPC Boiler

Gasifier

Fly Ash(Powder)

Molten Slag
(Glassy Granular)

Volume 100%Volume 40%
資料333

石炭焚
PC
Boiler
フライアッシュFly Ash

3~5%

IGCCスラグ
Gasifier
Slag

<0.1%

Advantage• Lower Slag Volume• Lower Unburned Carbon⇒ Utilized as Industrial Material• No Leaching from Slag
All Verified in Demo. Plant© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

Experience of MHI Low Calorie
Gas Firing GT

9Under Operation

Under Construction

Total

28

11

39

Capacity

3,088 MW2,614 MW5,602 MWOperating
Hours

More than 1,500,000-

More than 1,500,000

No. of Units

As of April 2010

300MW Plant Overall Equipment
5,000

25

4,000

20
3,000

Capacity
15

2,000

Unit NOS.
10

1,000

5

Total Capacity (MW)

Total Nos. of Operation Units

30

15
1990

1995

2000

資料334

2005

Year

© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

IGCC System Configuration
with Carbon Capture
CO+H2O

CO2+H2

10

Sulfur
SRU
Steam

Coal

Air-Blown
Gasifier

CO Shift

CO2
AGR
AGR

H2 Rich Syngas

N2

Air

Combustor
O2

ASU-N2

Sequestration

CO2
Comp

Air
GT

Air
Booster

Comp

G

ST

G

Air for Gasifier
HRSG

資料335

© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

H2 Rich Gas Experiencein MHI Gas Turbine

11

Actual Combustion Test for National ProjectH2 CONTENTS IN FUEL GAS (vol %)100

MHI EXPERIENCEMark

Kind of Gas

NOx Control

Syngas

N2 Dilution

80

COG

None

70

RefineryGas

Steam
Injection

90

A Plant

176,100hrs

B Plant

166,900hrs
Summary

C Plant
60

51,400hrs

Stand-by
D Plant

157,200hrs
105,300hrs
E Plant

50

F Plant

187,500hrs

40

G Plant

I Plant

30

Operating
Hours>1,670,000

Typical Air-blown IGCC
(with CO2 captured)
51,700hrs

J Plant
K Plant

123,300hrs

177,000hrs
165,300hrs

10

0

12

181,300hrs

H Plant

20

146,100hrs

Nos. of Unit

6,000hrs
1965

1970

1975

1980

1985

1990

資料336

1995

2000

2005

2010

© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

12Comparison in IGCC Systems

140

C A P E X (% )

100

92
105

(Net Power Output)

100

100

97

80

0

80

60

60
40

40
20

20
0

($)

3%(abs.)

Air-Blown

100

100

120

Net Power Output (%) Net Plant Efficiency [%]Air-blown IGCC has merits of better plant efficiency,
resulting in lower CAPEX.

($/kW)

Air-Blown($)($/kW)

0

O2-Blown
2.5%(abs)
20

40

60

80

100

CO2 Removal [%]CAPEX in $CAPEX in $/kwnet
Net Power Output

O2-Blown

Note ) This chart is the comparison inside MHI
for the case of 65% or more CO2 capture.
資料337© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

Mitsubishi IGCC
Technology Development

13

Fuel Capacity (ton/day)

250MW / 1,700t/d
Demo. Plant CCP
500MW or More
Commercial Plant

10,000
5,000
1,000
500
200t/d Pilot Plant(Nakoso)

Successful operation- National Project in Japan Ensures Quality & Performance

100
50
10
5

Pilot Test Plant(MHI Nagasaki)

2t/d PDU(CRIEPI)

1
1980

1985

1990

1995

2000

2005

2010

2015

2020

2025

PDU : Process Development UnitCRIEPI : Central Research Institute of Electric Power Industry© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.
資料338

250MW
IGCC Demonstration Project

14

Ministry of Economy, Trade and Industry

METI
30% Subsidy

70%
Hokkaido EPCo.
Contribution Tohoku EPCo.

NakosoTakasago

Joint Project Agreement
Nagasaki

Tokyo

Tokyo EPCo.
Chubu EPCo.
Hokuriku EPCo.
Clean Coal Power
Kansai EPCo.
R&D Co., Ltd.
Chugoku EPCo.
Shikoku EPCo.
Kyushu EPCo.
Researchers J-PowerCRIEPI

Yokohama
250MW Air-blown IGCC, Nakoso

HRSG

Gasifier

GT / ST

MHI

Single Point Responsibility(EPC Turn-Key Contract)

Gas Clean-Up

Project is Going on Schedule. Operation Started September, 2007.
2007
2001

2002

2003
Design

2004

2005

2006

2007

Construction (36M)

資料339

2008

2009

2010

Operation
14© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

250MW IGCC Demonstration Project15- Targets & Accomplishments IGCC has been successfully achieving the operation targets.
Targets

Past
Achievements

250MW

250MW

>42.0%net (LHV)

42.9%>99.9%>99.9%<8ppm<5ppm<4mg/m3N

1.0ppm
3.4ppm<0.1mg/m3N

Coal Kinds

Bituminous
Sub-bituminous

Chinese, PRB &IndonesianStart-up Time<18hrs

15hrs

Minimum Load

50%

50%

Ramping Rate
Long-term
Continuous
Operation
Long-Term
Reliability Run

3%/min2.4%/min2,000hrs

2,039hrs

5,000hrs

5,000hrs

OutputPerformance Efficiency

Emission

Operation
Flexibility

Reliability

CarbonConversion
SOx
NOx
Dust

Source:CCP

資料340

Future Plan

ExpandingMaximizing© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

ZeroGen in Australia
IGCC + CCS Commercial Project•

ZeroGen Pty Ltd. owned by the Queensland state government ofAustralia decided to start with MHI her world-first IGCC+CCS
flagship project.

•

CCC (Clean Coal Council), the QLD state government, officiallyapproved to start the commercial scale project (530MW) with MHI,
by highly evaluating the successful results of the 250MW Nakoso
demonstration project.

16

Principal Specification

Major Events

Coal
OutputGasifier
Gas Turbine
Carbon Capture
CO2 Storagez Coal gasification test using MHI’s Pilot
Plant was successfully completed.
: 4/E
z FS Report was issued and submitted to
the Federal Government.
: 6/E
z Third Party Review to the Report was
finished to highly evaluated results.
: 7/B

Australian Hard Coal
530 MWgross
Air Blown. Dry Feed
M701G2 GT (1 on 1)
65-90%
2-3 Mil.ton/yr

Feasibility Study was successfully completed andfurther optimization study has started.
資料341© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

IGCC Commercial Plant is Ready- Typical Expected Performance -17

CO2reduction
CO2

削減

15%~
-20%
30%

Item
Coal

50

Net Efficiency (LHV %)

48
46

250MW

48%
50%(Dry C/U)

700
600
500
400
300

50Hz/60Hz

200

40

(Net)

600MW/500MW
550 MW/450MW

Gasifier Oxidizer
Coal Feed

Air
DryAcid Gas Clean-up

Wet MDEA

M701G/M501G ×1(1 on 1)Net Efficiency(LHV%)
48 %Gas Turbine

44
42

Bituminous Coal

MW Output (Gross)
Gross Output

600MW(50Hz)
500MW(60Hz)

Specification

42%

w/o CCS

330
330

Note: Plant performance like output and efficiency
depends on site conditions including coalproperties.
properties.
Emission performance like SOx,
SOx, NOx and PM
can be discussed, depending on the regional
regulation.

140
140

38
Demo. Plant Commercial Plant
701G2 G/T
701DA G/T
501G2 G/T

(50% with Dry gas C/U)

資料342

© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

Typical Scope of Work
(Air-Blown IGCC)
Study
Scope
Interface18

HRSG &
SCR

ASU
Stack

Coal
Handling

Coal
Bunker &Coal
Grinding

Gasifier&
SyngasCoolerAGR &CO2
CaptureSwitchYard
Gas
TurbineSteam
TurbineCondenser

Water
Treatment

Slag
Handling

Evap
Pond

Raw
Water

SulfurRecoverySulfurHandling

資料343

CO2
Compressor

CO2
Sequestration

Air
Compressor

NaturalGas

Generator

Cooling
Tower

Mitsubishi
Partner
Owner© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

19

Future Innovation Activities
Gross Thermal Efficiency (LHV%)

1. Improvement of Thermal Efficiency
70
Ultra
Ultra HighHigh temp.
temp. GTGToo(1,700(1,700 C
C))
65

60

IGFC
IGFC

JJ typetype GT
GT

NGCC
NGCC

1,700
1,700ooC
C GT
GT(Natural(Natural Gas)
Gas)

Hot gasClean-up
System

JJ typetype GT
GT

55

IGCC
50

G
G typetype GTGTUSC(coal)
USC(coal)
45

40
1990

1995

2000

2005
資料344

2010

2015

2020

2025

© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

20

Future Innovation Activities
Source : WEC Survey of Energy Resources 2008
BP Statistical Review of World Energy 2008

Russia(157.0 bil. ton)

Europe(78.1 bil. ton)

Canada(6.6 bil. ton)China
(114.5 bil. ton)

MHI Technology
LigniteOther Africa(0.2 bil. ton)India
(56.5 bil. ton)

Other Asia
(41.9 bil. ton)

Sub-Bit.

Indonesia(4.3 bil. ton)
South Africa(48.0 bil. ton)

Near-Future
ExpandingAustralia(76.6 bil. ton)

Bit.

High moist. coal : 41.2 bil.ton- Scenario of utilization -World Total(844.1 bil. ton)

U.S.A
(242.7 bil. ton)

Colombia(7.0 bil. ton)

Present
Applicability
Other
South America(9.3 bil. ton)

Low Grade Coal Firing IGCC

2. Effective Utilization ofLower Grade –More Highly Moistened Coal
PrePre-Drying
System*System*＋*Pre-Drying may be applied to the future expanding part, to moremoistened lignite. © 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.
資料345

CCT promotion with
MHI’s Gasification Technology

21

Contribute to Both of the Power Generation and theChemical Industries by Gasification Technology<Power(*1)>• IGCC★ Highest Plant Efficiency★ Economical Merits
Integrated coal Gasification C/C

Coal<Chemical (*2) >Coal• SNG、CTL、DME Plant• Chemical Plant (NH3,Uera )★High gasification efficiency★Low Utility Consumption

Oxidizer

Reducto(Gasification)r

Char

Combustor(Combustion)(Air or O2)

Slag
Water

Chemical (Methanol) Plant

Note ; *1 :Air-blown*2 :Oxygen-blown:
資料346© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

22

Smart Low Carbon Fuel Production- DME・SNG Supply Chain from Low Rank Coal DME :Dimethyl ether (CH3OCH3)

SNG：Substitute Natural Gas

Utilizing LRC (Lignite) as export commodity

Assuring Clean Alternative
Energy (Liquid/Gas Fuel)Japan

Australia/Indonesia
Maritime
Transportation（DME・SNG）

Residence
Transportation

Lignite Mine
Power Plant

CTL plant
Productions of Synthetic Fuel

Transportation

Fuel
Utilization

Fuel Production Flow by Coal Gasification
Coal

Gasification

Gas
CleanUp

Synthesis

Fuel Utilization

Synthetic
Fuel

Diesel Engine

Boiler
Gas Turbine○ Synthetic Process can be constructed based on MHI’s Experiences○ Possibility of CO2 absorption plant● Other merits for Japan; Optimizing energy security portfolio by utilizing oil alternative fuel, Application ofabundant coal reserves by international cooperation with coal producing countries and, Checking for rising© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.
LPG and LNG prices by using DME.
22
資料347

CCT International Corporation

23

Utilization of CCT in APEC countries
Effective
Effective application
application ofof coalcoal
and
and advanced
advanced technology
technology
development
development inin Japan
Japan

JapaneseJapanese technological
technological support;
support;participation
participation inin CCT
CCT projects
projects

Japanese CCT

High-efficiency
Coal-fired PowerTechnologies(USC/IGCC)
CO2 Reduction

Environmental
Environmental technologies
technologies(flue(flue gas
gas andand coal
coal ashash handling,
handling, CCS,
CCS, etc.)
etc.)

Synthetic fuel(DME/SNG etc)

ＣＣＴin coal mine
・Australia (ZeroGen,
Brown Coal)・Indonesia (LCR)
・China (LCS ,Power
Plant Business)
・India↓・USA/Canada
・EU etcfrom Low Rank Coalfrom Low Rank Coal
Coal gasification
Low Carbon Fuel with CCS
Purification/fuel synthesis
CO2 Reduction
資料348© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

24

Summary¾ CO2 reduction in Coal Power Plants is one of Key factor
for Low Carbon Society.
Introduction of IGCC Commercial plant following USC
and the preparation for CCS・High Efficiency of Thermal Power Plant (USC,IGCC)・CCS (Pre Combustion, Post Combustion）
・Low Carbon Fuel for Power Plant from Low Rank Coal (DME、SNG)

CCT：Clean Coal Technology,

DME：Di-Methyl Ether , SNG：Synthetic Natural Gas
資料349© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

25

資料350

© 2010 MITSUBISHI HEAVY INDUSTRIES, LTD. All rights reserved.

Overview of U.S. Department ofEnergy’s Gasification Program
Scott M. Smouse
Senior Management & Technical Advisor – International
Strategic Center for Coalscott.smouse@netl.doe.gov
資料351
Chinese Delegation Visit October 19, 2010

Gasification Program Goal
Reduce the cost of electricity, while increasing power
plant availability and efficiency, and maintaining
the highest environmental standards

Key Research Areas:• Ion transport membrane O2 technology• Warm syngas cleanup and CO2 capture• High pressure, solids feed system• Longer refractory and sensor life
• Improve models from gasification kinetics
through to plant simulation
2

資料352

"Coal is an abundantresource in the world ...
It is imperative that wefigure out a way to use
coal as cleanly as
possible.“- Dr. Steven Chu,
Secretary of Energy

Key Gasification R&D Areas
APC’s Oxygen Membrane
Hot
Compressed
Air

Lean Air

RTI ‘s Warm Gas Cleaning
O2e-

Oxygen• Efficiency increases by 2.9%pt• COE decreases by 12.0%

Fuel Gas

Eltron’s H2/CO2
Membrane

Reduces capital cost by
1/3 - 5.0% reduction in
COE

WaterGas Shift*

Low-rank Coal*
Alternative Feedstocks*• Energy security• Carbon footprint
reduction

Process improvement
and intensification

Improve RAM*
• Refractory durability• Dynamic simulator• Feed system reliability• CFD gasifier modeling• Heat removal/integration • Slag model development• Temperature measurement & control
3

資料353

H2 H
CO H

H

2

H

H2 H

H

CO2 H

H

H2

H2 RichStreamH2

CO2* Advanced Gasification

Development of ITM Oxygen Technology
Air Products and Chemicals, Inc
Status• Testing commercial-scale

membranes and modules in 5-TPD
pilot facility- Operated under full driving force
conditions- Met/exceeded wafer performance forflux and purity- Cycled modules from idle to operating
conditions w/o loss of performance- 0.5 and 1 TPD module tested;
optimization ongoing• Construction of a 100-TPD

Future Work2005

Benefit

0.5 TPD
Stack• Process modeling and conceptual design of 2,000+ TPD ITM plant• Conduct system analyses of air separation unit – ITM hybrid systems• Higher efficiency, lower operating cost and capital cost,
CAPEX - 25% less than cryogenic state-of-the-art systems
4

資料354© Air Products and Chemicals, Inc. 2009. All Rights Reserved

1.0 TPD Stackintermediate-scale test unit by year
end, startup by the end of 20112008

High Pressure Solids Pump
Status• Pump component testing nearly complete• Final design of prototype pump complete• Lab-scale tests complete and analysis ongoing ofcoal/biomass blends to:- Predict transport behavior- Estimate economic impact of using biomass- Select most promising blend for further testing

Future Work (to be completed by 2013):• 600 TPD pump testing at EERC
• 400 TPD life-cycle testing• Conduct gasification economic analysis• Complete pump model and analyze economic
potential using test data

PWR Pump

Benefit:• Reduce heat penalties with slurry feed and high-moisture (western) low-rank coals
5

資料355

Scale Up of High-Temperature Syngas Cleanup Technology
Research Triangle InstituteComplete 5,000 hours of operation of warm syngas cleaning technologies
Description• Design and construct 30-50 MWe prototype system• Operate all warm syngas cleaning technologies atcommercial operating conditions, including:- CO2 capture using aMDEA test unit, with CO2compression and water gas shift optimization• Perform CO2 sequestration including test well andCO2 measurement, monitoring, and verification

Polk Power Station Unit 1

Benefits• Integrating this technology with carbon capture results in increase of 11% in net
thermal efficiency and 12% reduction in WGC capital cost
• Allows demonstration of high-purity syngas of at significantly lower costs
than current technology
6

資料356

Scale-up of Hydrogen Transport Membranes for IGCC Plants
Eltron Research & Development Inc
Description• Design, build, and operate small pilot-scale(250 lb/d) hydrogen membrane reactor for
separation of pure hydrogen from coal-derived
shift mixtures

Status• Tested in1.5-lb/d unit, achieved high flux andproduced high-purity H2• Begin construction of 12-lb/d reactor and skid
package soon – operational FY 2011

Conceptual design of a commercial membrane unit

Future Work• Construction and test of 250-lb/day unit at Eastman• Complete design through construction and testing of next phase, 4-10 TPD

Benefits• 17% overall capital cost reduction• 3.3 percentage point increase in efficiency for industrial size plants• Reduces costs of integrating CCS because CO2 exits HTM in concentrated, high-pressure
stream7

資料357
Eltron Research & Development Tech Brief http://www.eltronresearch.com/docs/Hydrogen_Membrane_Technology_Summary.pdf

Improving RAM(Reliability Availability Maintainability)
Gas Technology Institute (GTI)
Development of optical sensor tomonitor coal gasifier flame
characteristics

Virginia Polytechnic Institute
Development of single crystal sapphire
optical fiber sensor for reliabletemperature measurements in slagging
coal gasifiers

NETL
Office of Research and Development• Development of new refractory materials
and slag behavior model• Development of IGCC Dynamic
Simulator• Computational Fluid Dynamics (CFD)
modeling of advanced gasifiers• Biomass characteristics database
Dynamic Simulator
and Immersive Training System
8

資料358

Research & Development
Gasification Projects
NETL
Office of Research and Development• Modeling– IGCC Dynamic Simulator Research & Training
Center– Co-gasification kinetics and product characterization– Development of carbonaceous chemistry forcomputational modeling– Absorption/regeneration transport desulfurizer
modeling for commercial-scale plant– Slagging gasifier model development and validation
using commercial experience• Biomass/ coal prep. for gasification systems– Database of biomass materials characterization, andfeed and gasifier operations impact• Evaluating– Refractories for slagging gasifiers including low- andno-chrome materials
9

資料359

Systems Analysis
NETL
Office of Systems Analysis and Planning• Assessments of individual and cumulative value oftechnologies under development• Optimization studies on project variables, and technology
integration with IGCC plant• Sensitivity analyses on external factors, such as carbon tax• Many analyses are open to the public and posted on NETL
websiteCost and Performance “Pathways”
study for Gasification with CCS –Bituminous Coal
Analysis on Website
10

資料360

Future Systems Analyses
NETL
Office of Systems Analysis and Planning• Low-rank coal pathways studies– Step-wise incorporation of technology
advancements• Sensitivity analysis between IGCC at lower
altitude site versus high-altitude mine-mouth• Liquid CO2 slurry feed analysis– Verifying benefits

11

資料361

IGCC Advanced Technology Assessments
Coal
Feed

Raw
Gasifier
Syngasand Syngas
Cooling

Gas
Cleanupand Shift

CO2
Separation
H2 FuelO2
Air

OxygenProduction

Air

N2

HydrogenTurbine

CO2

Hot
Flue
Gas

CO2
Compression

CO2
Transport,
Storage andMonitoring

Steam
Bottoming
Cycle

Flue Gas
To Stack

Technology Advancements
Coal Feed System

Slurry Feed

Coal Feed Pump

Oxygen Production

Cryogenic Air Separation



Ion Transport Membrane

SelexolWarm Gas Cleanup

Gas Cleanup
Turbine12

Adv F

Adv H2 Turbine



CO2 Separation

Selexol

Capacity Factor

80%



H2 Membrane


85%


資料362

Next Gen Adv Turbine

90%Driving Down the Cost of CCS
with Advanced Technology (IGCC)
Cost of Electricity (COE) decreases by 30%
120

First-Year Cost of Electricity (2010$/MWh)

110
100

IGCC with capture

90
80

IGCC w/o capture

70
60Supercritical PC w/o capture
50

13

資料363

90%
Availability

Adv.
Turbine (II)

ITM

Adv.
TurbineH2
Membrane

Warm
Cleanup85%
Availability

Coal Pump

Reference40

Driving Down the Cost of CCS
with Advanced Technology (IGCC)Net Efficiency Increases by >7 Percentage Points

Net Plant Efficiency (%, HHV)

50

40

IGCC / Supercritical PC
w/o capture
IGCC with capture

30

20

10

14

資料364

Adv.
Turbine
(II)

ITM

Adv.
TurbineH2
Membrane

WarmCleanup

Coal
Pump

Reference0

2010 Industry Interviews - Purpose
Determine and Resolve Most Significant Technical Impediments to
Widespread Commercial Gasification-Based Power Production

Changes since 2001 impacting Gasification Industry• Economic slow down - financial markets crisis• Administration change - focus on sequestration
 Increasing global climate change concerns Impending carbon management regulations• Extreme changes in oil & natural gas prices
1412$/ Mcf

10
8
6
4
2
0
Jan 2006

Jan 2007

Jan 2008

Jan 2009

Henry Hub price
15

資料365

Jan 2010

Visit NETL’s Gasification Website

www.netl.doe.gov/technologies/coalpower/gasification/index.html

16

資料366

(8)特別講演 6

資料367

GLOBAL CCS INSTITUTESUPPORT TOWARDS CCS DEMO PROJECTSMark Bonner – Global CCS InstituteAsia-Pacific Economic Cooperation (APEC): Clean Fossil Energy Technical and Policy Seminar
APEC EXPERT GROUP ON CLEAN FOSSIL ENERGY, FUKUOKA JAPAN 27-29 OCTOBER 2010
資料368

WWW.GLOBALCCSINSTITUTE.COM

Slide 1GLOBAL CCS INSTITUTE

PRESENTATION OUTLINE
1. Global context
2. GCCSI role
3. Status of CCS projects
4. Challenges / opportunities
5. GCCSI support

資料369

Slide 2

GLOBAL CCS INSTITUTE

資料370

Slide 3 2

GLOBAL CCS INSTITUTEESSENTIAL AND SUBSTANTIVE ROLE TO FULFILLPRESERVING GLOBAL CARBON BUDGET (ENVIRONMENT)IN A COST EFFECTIVE MANNER (ECONOMY)
WHILE ENSURING SECURITY OF SUPPLY (ENERGY)

Up to 20% ofabatement
required by 2050

資料371

Slide 4

GLOBAL CCS INSTITUTECCS SOLUTIONS FOR INDUSTRY AND THE CLIMATE(in 2050)
Power applications(~50%)

Industrial applications(~25%)

Alternate fuel applications(~25%)

資料372

IEA, CCS Roadmap

Slide 5GLOBAL CCS INSTITUTE

CCS: A ROADMAP TO 2050
12,00010,000Captured CO2 (MtCO2/yr)

8,000

6,000

2050
3,400 projects
OECD (35%)
Non-OECD (65%)

OECD PACIFICUSAOTHER OECD N AM
OECD EUROPE
ODA
ME
INDIA
EEU + FSU
CSA
CHINA
AFR

2040
2,100 projects
OECD (40%)
Non-OECD (60%)

2030
850 projects
OECD (49%)
Non-OECD (51%)

4,000

2,000

2015
18 projects
OECD (72%)
Non-OECD (28%)

2020
100 projects
OECD (50%)
Non-OECD (50%)

0
2010

2015

2020

2025

2030

2035

2040

2045

2050

資料373

IEA: A 2009 View

Slide 6

GLOBAL CCS INSTITUTE

資料374

Slide 7 6

GLOBAL CCS INSTITUTE

A UNIQUE COMMITMENT TO HELPCOMBAT CLIMATE CHANGE
 On 9 June 2009, the Global CCS Institute was launched at G8 /Major Economies Forum (MEF) meeting in L`Aquila, Italy
 Launched by the then Prime Minister of Australia, The Hon Kevin
Rudd MP and US President Barack Obama― Prime Ministerial support from Canada, Italy, Republic of Korea,
Mexico and UK

資料375

Slide 8

GLOBAL CCS INSTITUTE

AN INDEPENDENT CCS AUTHORITY – SOLE FOCUS
 The Global CCS Institute is a not-for-profit company limited byguarantee under the Australian Corporations Act 2001
 Membership is open to governments, industry and NGOs
 International Advisory Panel consists of:– Sir James D. Wolfensohn– Ms Leena Srivastava– Mr Claude Mandil– Lord Nicholas Stern– Prof Zeng Rongshu– Mr Russell Higgins AO

資料376

Slide 9

GLOBAL CCS INSTITUTE

WHAT WE DO
The Global CCS Institute connects parties around the world to solve
problems, address issues and learn from each other to accelerate thedeployment of CCS projects by:

1. SHARING KNOWLEDGE


Collecting information to create a central repository for CCS knowledge

Creating and sharing information to fill knowledge gaps and build capacity

2. FACT-BASED ADVOCACYInforming and shaping domestic and international low carbon energy policiesIncreasing the awareness of the benefits of CCS and the role it plays within aportfolio of low carbon technologies

3. ASSISTING PROJECTSTackling specific barriers, particularly amongst early movers

Bridging knowledge gaps between demonstration efforts

Knowledge
Sharing

Fact-Based
Advocacy

Assisting
Projects

資料377

Slide 10

GLOBAL CCS INSTITUTE>260 MEMBERS
Governments Agencies

Scope for action(80% of world’s emissions)

NGOs and Development
Organisations

Research Institutes

Developing
countries
outreachFact based
information

Relevance through bestpractice standards

Industry Bodies and Private Corporations

資料378
Note:

Non exhaustive list of members

Slide 11

GLOBAL CCS INSTITUTEKNOWLEDGE SHARING CAN:•

Assist development of CCS projects•

Support cohesion of the global CCS community•

Accelerate cost reduction•

Drive innovation

Innovation
Exchange

GlobalConnectivity•

Establish best practice•

Support capacity and capability building•

Increase public awareness and education

Project
DeliveryAccelerating
CCS
through
Knowledge
Sharing

Stakeholder
Communications

Commercial
Interests

Fact Based
Advocacy

資料379

Slide 12

GLOBAL CCS INSTITUTE

COORDINATED AND CONSISTENT GLOBAL EFFORT TO
HELP ACCELERATE CCS DEPLOYMENT
pre-commercial/portfolio demonstration  broad commercial deployment (power, industry, fuels)

diverse range ofutilisation
opportunities,
mitigation needs,
operatingenvironments, anddeployment
capacities

private-public
sectorinvestments
and capacity
building
資料380

strengthening
existing skill sets andinstitutional
capabilities toassess, adapt, anddeploy integrated
CCS solutions tolocalised conditions

Slide 13

GLOBAL CCS INSTITUTEA CRUCIAL ROLE AND DEFINITIVE PURPOSE
long-term outcomes supported by near-term targeted action

Key global
playerRespond to andinform country driven
requests andrequirements(including
Government’s,
industry and all CCS
stakeholders)

RemoveCCS Barriers

Create an environmentthat supports CCS
applications

Knowledge
broker

Provision of evidence
based information andderived knowledge

資料381

Slide 14

GLOBAL CCS INSTITUTEGCCSI – STRATEGIC KNOWLEDGE PRODUCTS•

Strategic Analysis of
the Global Status of
CCS•

Portfolio of CCS
Projects•

CCS Ready•

Global CCS Institutesupported the reportto the G8•

Major Economies
Forum Technology
Action Plan (TAP)
資料382

http://www.globalccsinstitute.com/general_information/reports_papers_documents.html

Slide 15

GLOBAL CCS INSTITUTE

FACT BASED ADVOCACY•KEY REPORTS


Global Status of CCS Report #1 September 2009, #2 due December 2010

Ideal Portfolio of Projects November 2009

Defining `CCS Ready` February 2010

CCS Project update May 2010, Project Summary to G8/G20 June 2010



Response to World Bank Energy Strategy Consultation June 2010



Response to UK CCS Stakeholder Engagement September 2010Collaboration on IEA CCS Roadmap `One year on` October 2010



Major Economies Forum (MEF) Action Group CCUS Stock Take Report due
late 2010/early 2011

• US STATE DEPARTMENT SUPPORT Award of US$500k to advocate CCS technology in support of MEF
 Re-use of CO2, scoping studies in developing countries, global storage gap
analysis, best practice for regulative/legislative
approaches with CCS projects
資料383
Slide 16

GLOBAL CCS INSTITUTE

FACT BASED ADVOCACY•KEY EVENTSMember Meetings – Canberra/April 2009, Paris/November 2009, Pittsburgh/
May 2010, Kyoto/October 2010Capacity Development Workshops – South Africa/September 2009,
Indonesia/November 2009, Malaysia/March 2010, Vietnam/March 2010, Abu
Dhabi/June 2010

Knowledge Workshops – Chicago/October 2009, Ottawa/March 2010

Finance Meetings – New York/September 2009, London/January 2010,
Washington/April 2010



Legal Symposia – New York/March 2010, Melbourne/March 2010

Public Awareness – Paris/November 2009, numerous project `one-to-ones`

CCUS events – China/September 2009, Algeria/May 2010, China/January
2010, Abu Dhabi/January 2010, China/August2010

Major conferences/speaking – approximately 120 engagements worldwide
since June 2009
資料384

Slide 17

GLOBAL CCS INSTITUTE

CRITICAL ACTIONS/ISSUES – INTERNATIONAL FORA

資料385

Slide 18

GLOBAL CCS INSTITUTE

WORKING WITH FUNDING PARTNERSASIAN DEVELOPMENT BANK
Clean Energy Trust Fund (CCS)•GCCSI has provided AUD $21.5M to the ADB under the Clean
Energy Trust Fund for CCS capacity building– Capacity strengthening in China

WORLD BANKNORWAY•The USD$8M World Bank CCS Trust Fund was establishedin Dec 2009 between World Bank, the GCCSI and Norway•

To support capacity with a focus on policy, legal andregulatory frameworks
資料386

Slide 19

GLOBAL CCS INSTITUTE

資料387

Slide 2019

GLOBAL CCS INSTITUTEGLOBAL TRENDS FROM GCCSI PROJECT STOCK-TAKE(2009 to 2010)•>10% increase inactive/planned CCS
projects•>50% increase incommercial projects
identified•~30% increase in thenumber of large scale
integrated projects•

Overall number ofprojects increased by~20%•

Nearly 75% increase inprojects
delayed/cancelled

資料388

Slide 21

GLOBAL CCS INSTITUTE

POSITION OF LARGE SCALE INTEGRATED PROJECTS BYASSET LIFE CYCLE STAGE

Over 85% ofidentified
projects inearly stages

資料389

Slide 22

GLOBAL CCS INSTITUTE

資料390

Slide 2322

GLOBAL CCS INSTITUTE

CRITICAL ISSUES IDENTIFIED BY MEMBERSHIPTECHNICAL•

Costs and performance uncertainty of scaling-up CO2 capture technologies•

Availability of suitable storage formations and cost-effective MMV technologies•

Development of multi-user CO2 transportation infrastructure (‘CCS Hubs’)

REGULATORY•

Issues around permitting (including environmental, health and safety)•

Defining appropriate MMV regimes given regulatory uncertainty– long-term liability– eligibility for greenhouse gas reduction credits– Recognition of enhanced hydrocarbon recovery projects as permanentstorage

SOCIAL CHALLENGES•

Public awareness
資料391

•

Community engagement and support

Slide 24

GLOBAL CCS INSTITUTE

資料392

Slide 2524

GLOBAL CCS INSTITUTE

PROJECT SUPPORT PROGRAM (PSP)The PSP objectives are:• help `kick start` early mover large demonstration
projects through targeted financial/knowledge support• allow the Institute to distil `learnings` in order to derive
best practices, and to be able to better inform andsupport other CCS projects facing similar challenges.

The PSP received nearly 50 submissions worldwide, almost
exclusively from developed countries – seeking over A$500M

資料393

Slide 26

GLOBAL CCS INSTITUTEIDEAL PORTFOLIO OF CCS PROJECTS - REPORT

75% across 5 priority regions

25% across other regions

資料394

LEK

Slide 27

GLOBAL CCS INSTITUTEASSESSMENT OF PROJECT AND PROPOSAL MERIT
high viability
facilitates integrated CCS
low risk

Applications ofhigh interest

PROJECT MERIT Technical viability Commercial viability
 Early implementation
 Lower risk

PROPOSAL MERIT

high value for money
high prospect of knowledge sharing

 Knowledge creation and sharing potential
 Added value to the existing Project Relevance to other Projects
資料395

Slide28

GLOBAL CCS INSTITUTEGCCSI FUNDING SUPPORTUNDER THE PSPFirst tranche of GCCSI funds

Australia• CarbonNet (Latrobe Valley, Victoria), A$2.3M― studies to advance commercial modelling for a hub concept― funding in strategic partnership with the Clinton Foundation―.initial study into a framework for MMV• Callide Oxyfuel Project (SE Queensland), A$1.83M― support Stage 2 of the project― facilitate an injection test of CO2 into a potential storage site
― Northern Denison Trough and other Qld locations― Stage 1 – Oxyfuel capture

Europe• Rotterdam CCS Network (Netherlands), A$2.2M― assessment of storage sites in the North Sea― a feasibility study into transport options for CO2― including shipping― case study on benefits of partnerships between industries• Romanian CCS Demonstration Project (Oltenia, Romania), A$2.55M― feasibility of a capture, transportation and storage demo
― examine costs and schedule for the full chain project― capture 1.5Mtpa of CO2 from existing Turceni plant
America• Tenaska Trailblazer Energy Center (Sweetwater, Texas), A$8.03M― concept definition studies― development of a new 600MW sub bituminous coal plant― 85 to 90% capture

Slide 29

• Tenaska New Technologies/Entergy Corporation (Louisiana)
A$0.826M― studies for retrofit of Roy S Nelson plant― capture technology; engineering, procurement andconstruction
資料396

GLOBAL CCS INSTITUTE

COVERAGE OF KNOWLEDGE SHARING REPORTS AND
CASE STUDIES

PublicAcceptance

Risk and theEnvironment

























Policy, LegalandRegulation

Finance andCommercial

CarbonNet

Case Studies

Storage and
MMVTransport/
Infrastructure

Project

CaptureFeasibility/FEED







Callide OxyfuelProject

Rotterdam CCS
Network Project







Romanian CCS
Demo Plant



Trailblazer
Energy Center

Nelson 6 CCS
Project





資料397

Slide 30

GLOBAL CCS INSTITUTE

資料398

Slide 3130

GLOBAL CCS INSTITUTE

REMARKS• Institute strategic framework to establish acceleration actions andfact based products to address urgent CCS deployment• Early large/commercial projects will be key• Sharing of knowledge gained, especially from early projects a
critical element• Institute aiming to engage with countries to understand theirneeds and to assist with trajectory towards CCS deployment“we need patience and wisdom …”
Mr Nakagaki (JCOAL-JAPAC): APEC reception dinner, 27 October 2010

Unprecedented need for effective collaboration worldwide
資料399

Slide 32

GLOBAL CCS INSTITUTE

資料400

32

(9)セッション 4A(i)

資料4012010 APEC Coal Seminar

Introduction to Research and Development
on Efficient Utilization of Low Grade Coals

Prof. Isao Mochida
Research and Education Center of Carbon Resources
Kyushu University

資料402

What are Coals of Low Grades?
Low Calorific Value(1) High Water Content - Low Ranking Coals
High Oxygen Contents(2) High Ash Contents(3) Low Ranking and High Ash Contents

Necessity of their Utilization

資料403

2010 APEC Coal Seminar, Fukuoka

Necessity of Utilization of Low-Rank Coal in Various Ways Coal, especially low-rank coal such as sub-bituminous coal, is abundant in comparison to other fossil fuels.
 Consumption of high quality coal such as bituminous coal and anthracite has been expanding at a rapid pace,keeping pace with the increase of coal demand in recent years. On the contrary, the consumption of low-rankcoal remains at a lower level.
 As low-rank coal, with higher oxygen and hydrogen composition, can be gasified or liquefied at lower
temperatures, it can be utilized in various ways after gasification and liquefaction.
 The development of advanced technology for the utilization of low-rank coal will contribute to the easybalancing between supply and demand of energy and mitigation of CO2 emissions in the coal producing
countries. In the results, it will lead to the further promotion of clean energy supply to Japan.

[Trend of reserve-production ratio by Coal Type]
1993

1996

1999
527
467

514504

2002
457

2005

2007

[Trend of Coal Consumption by Coal Type]（Million tonnes）
5,000

416

4,000
339
250 238

164156 172

139

Bituminous including
Anthracite
Sub-bituminous

3,000
190 172

170

2,000

97 85

Lignite

1,000
Bituminous including
Anthracite

Sub-bituminous

Lignite

0
1993

1996

1999

2002

2005

2007

Source: WEC, “Survey of Energy Resources Interim Update 2009

Source: WEC, “Survey of Energy Resources Interim Update 2009
資料404

2010 APEC Coal Seminar, Fukuoka

[Major Lignite Consuming Countries][Recoverable Reserves by Coal Type]

Lignite
150 B tonnes
18%826
billion tonnes

Germany
175 Mt18.4%

Others264 Mt27.7%

Bituminous
including
Anthracite
411 B tonnes
50%

Romania
35 Mt
3.7%
India
35 Mt
3.7%
Canada43 Mt
4.5% Czecho
50 Mt
5.3%

Sub-bituminous
265 B tonnes
32%

953
milliontonnesPoland60 Mt
6.3%

Russia76 Mt
7.9%
Turkey73 Mt
7.7%
Australia
72 Mt
7.6%

United States
69 Mt
7.3%

Power Generation Shares in Some Countries
Greece : -90%, Germani : -75%
Poland : -55%, India : -55%
Australia : -25%, Russia : -45%
USA : -10%, Czech : -50%
資料405

2010 APEC Coal Seminar, Fukuoka

Quality of Lignites : moisture and ash content

High-ash and/or High-moisture containing coals (often termed as lignites) – their location,and calorific Values (LMV, Mj/kg); country labels as follows:
1: Australia; 2: Indonesia; 3: India; 4: USA (Texas, North Dakita); 5: Germany; 6: Greece,
資料406
7: Spain; 8: Poland; 9: Czech Republic; 10: China;
11: Turkey; 12: Rpmania
Source : various; IEA, 20092010 APEC Coal Seminar, Fukuoka

Effect of Moisture Content in Lignite on Boiler Size

資料407

2010 APEC Coal Seminar, Fukuoka

6

Principles of Drying
Vaporization•Above 100oC : Steam, Hot Water, Hot Oil, Tube Heat
•Below 100oC : Replacement of Wet Atmosphere, Drying Gas of Low Humidity,
Heating is Helpful.
Press / Grinding•Mechanical Dewatering
Extraction•High Temperature / High Pressure ~360oC : Supercritical Water•Low Temperature / Low Pressure : DME
Coking•Use of Waste Heat and Gas is Key.

Drying is still Costy!
資料4082010 APEC Coal Seminar, Fukuoka

資料4092010 APEC Coal Seminar, Fukuoka

Power Plant Flow with Steam Tube Dryer Drying Process

資料410

2010 APEC Coal Seminar, Fukuoka

Configuration of Steam Tube Dryer

資料411

2010 APEC Coal Seminar, Fukuoka

Schematic of Plant Layout,
Showing Air Heater and Coal Dryer, North Dakota Brown Coal
Humid Air to Be Condensed → Lower Humidity?
Dust
Is High Temp Available?

資料412

2010 APEC Coal Seminar, Fukuoka

Coal Moisture Content Versus Time for Test36.
Comparison of Theory and Experiment(65.5oC)

資料413

2010 APEC Coal Seminar, Fukuoka

12Drying Apparatus by Waste Gas
Dry CO2 Gas
50~80oC

Wet Coal Lock

Waste Heat

conveyor

Mesh
Thickness

Cooling(Dehumidification)

Moving Rate; 0.5~1m / min
Mesh; 1~1mn
Thichness of Coal; <0.30mm

Wet CO2 Gas
40~50oC

Dry Coal

Water

資料414

2010 APEC Coal Seminar, Fukuoka

Block Flow of UBC Process (Kobe)
Fine Coal
350KPa140oC

SlurryDewatering

100KPa130oC

100KPa150oC

Coal/Oil
Separation

Oil
Recovery

Recycling Oil

Briquette▪ No Chemical Reaction▪ High Thermal Flux
▪ Product Stabilization
資料415

2010 APEC Coal Seminar, Fukuoka

♣ CWM Using Brown Coal• Supercritical Water Drying• Mixture Preparation
Details are Presented by JGC.

♣ Chinese Activity on Inner Mongorian Lignite• Drying and Pyrolisis

資料416

2010 APEC Coal Seminar, Fukuoka

Lurgi Gasifier at North Dekota♣ Moving Bed Gasifier
Syn Gas to SNG, pipeline
Chemicals and tar
CO2 → EOR in Canada

資料417

2010 APEC Coal Seminar, Fukuoka

HRL-IGDCC Process Flow
H2O

Participation of Harpin Electric
資料4182010 APEC Coal Seminar, Fukuoka

Generator
Electricity

Super Critical Steam
CycloneSynthetic Gas

Reformer

CycloneCatalytic Reformer
Honeycomb Catalyst Bed
Catalytic Reformer
Dried CoalChar
Combustor（FBC）

Coal Layer

Pyrolyzer; 500-600oC
Hot GasHot Particles
Ash and Char

Down Flow Moving Bed
Hot Gas Pyrolysis and Gasifier
Gasifier; 700-800oC

Sorbent
Ash
Discharge

Char Ash Particles
O2/CO2

Not Combined Cycle
Electricity is Produced only Thermally.
But CO/H2 Can Give Chemicals and Fuels.

Low Cost Fluidized Bed, Low Rank Coal of High Volatiles
Kyushu Electric / Kyushu
資料419 University
2010 APEC Coal Seminar, Fukuoka

Gasification by Enytrained Bed
Ecopro, NSE is now under feasibility study.
High Volatile Content of Low Ranking Coal Must Be Highly Utilized.
Low Melting Ash of Victorian Brown Coal↓
Lower Temperature Gasification

資料420

2010 APEC Coal Seminar, Fukuoka

Brown Coal Liquefaction
1990’s Japan / Victorian Project
50 ton / day Pilot Plant♦Target ProductCoking Binder to Gasoline and Diesel
Strongly Subjective to Petroleum Price
Chinese Shenha Liquefaction Project
Now
資料421

2010 APEC Coal Seminar, Fukuoka

How to Prepare the Coke More Efficiently fromLower Rank Coals?
Coal

Coke Oven

Formed Coking

Pretreatment

Pretreatment

Oven Coking

BinderPartial Briquetting

Coke

BinderForming

Formed Coking

Binder is a Key for Both Processes.

Coke
資料422

2010 APEC Coal Seminar, Fukuoka

Codrying, Copyrolysis and Co-gasificationof Brown Coal and Biomass
Similarity↓
Mass-Treatment

Cost Down
Waste Treatment
資料423

2010 APEC Coal Seminar, Fukuoka

Combustion or Gasification of High Ash Coals

High Ash Coal is Abundant and Widely Distributed over the World.
How to Use High Ash Coal May Be A Key in the World Demand.
Key is to Reduce the Ash Problems.
Heat Capacity Errosin, Corrosion, Adhesion.
Normal Pressure or Pressurized Fluidized Bed Combustion.
Short Range Transfer of Ash Must be Desinged.

資料4242010 APEC Coal Seminar, Fukuoka

XRF Ash Analysis of Victorian Brown Coal and Indian Coals
JIS(M8815) Mass (wt%)

XRD Pattern of Raw Coal and Ash

Q

815oC AshK

300oC Ash
K

Coal

10

Q:Quartz- SiO2
Q:quartz-SiO2
K:Kaolinite-Al2(Si2O5)(OH)4
K:kaolinite-Al2Si2O
D:Diopside-Ca(Mg,Al)(Si,Al)
2O6

Q

Q
QQ Q
Q
K

Q
K

K

Q

Q

Q Q

Q C D
k

Q
Q QK
KQKQ Q Q

k

k

Q
QQ Q
QQ
Q Q Q
k

Q
k

Q

K

20

Indian coal

Q
Q
Q QK
KQK Q Q

30

2θ

40

50

60

10

20

Brown coal
資料425

30

2θ

40

50

60

IndianVictoria

SiO2

86.44

33.30

Al2O3

8.66

17.60

Fe2O3

1.26

16.56

CaO

0.86

16.80

K2 O

0.14

1.10

TiO2

1.77

1.26

SO3

0.72

6.27

P2O5

-

-

SrO

0.01

0.02

MnO

0

0.19

V2O5

0

0.07

MgO

0

6.64

ZrO2

0.04

0.01

Y2O3

0

-

ZnO

0

-

CuO

0.02

-

Rb2O

0

-

Total
ash

48.4

2.49

2010 APEC Coal Seminar, Fukuoka

24

Revival of Fluidized Bed• High Ash Content, High Temperature Melting Ash, Coal
• Lower Temp –Catalytic- Long Residence Time
• Bubbling vs Circulating – Solid Transportation• Normal or Higher Pressure

資料4262010 APEC Coal Seminar, Fukuoka

25

Outline of PFBC Process

370MW Commercial IGCC Limited Efficiency

資料4272010 APEC Coal Seminar, Fukuoka

Integrated Complex for Low Rank Coal

Low rank coal

MethaneSynthetic
gas(CO+H2)COAL
GASIFICATION

ChemicalComplexTransit
Point

Mine mouthGas
treatment

SNG
Plant

MarketGas firedPower plant

Electricity

LNG
Plant

LNG
Methanol

MTG
Plant

Methanol
Plant

DME
Plant
CO2

FUEL

Gasoline
DME
MTO
Plant

Propylene
Other Chemicals

CCS
EOR
ECBM

Hydrogen
Plant
CO2

HydrogenOil refinery

Chemicals

Ammonia
Plant

CO2

Ammonia
Urea
Plant

Urea

Chemical derivatives；資料428
Acetic acid, Acrylic acid, Urethane and so on
2010 APEC Coal Seminar, Fukuoka

Waste of Low Grade Conversion
Water, Minerals

By-Products
In the Integrated Complex

資料429

2010 APEC Coal Seminar, Fukuoka

Thank you for your attention!

資料430

2010 APEC Coal Seminar, Fukuoka

APEC Clean Fossil Energy Technical and Policy Seminar 2010

Low Rank Coal Utilization
by HWT
28 October, 2010
JGC CORPORATION
Yoshiki Ueno
資料431

1

JCF(JGC Coal Fuel) from Lignite
Low Rank CoalHWT Upgrading

Slurrification

Coal Slurry- High moisture- 330deg-C/15MPa- Dehydration(JGC Coal Fuel)- Low Calorific Value- Deoxidization- Pulverization- Low Ash & Sulfur- Dehydration- Mixing with dispersant

資料432

2

Contents
1. Upgrading by Hot Water Treating (HWT)of Low Rank Coal (LRC) and Slurrification
2. Experimental Results
3. Demonstration Project

資料433

3

HWT : Hot Water Treating
LRC

Upgraded LRC
HWT Upgrading¾High Porosity¾High Moisture Content

300 - 330 deg-C
12 - 15 MPa
30 min¾Low Porosity by Sealing with Tar¾Low Moisture Content¾High Carboxyl Content¾Low Carboxyl Content by Decomposition¾Hydrophilicity¾Hydrophobicity
資料434

4

CS (Coal Slurry)
 Liquid type fuel similar to heavy fuel oil(Coal derived substitute fuel for oil)
 Closed storage and transportation
 No dust problem, no spontaneous ignition
CS Properties
Calorific Value(HHV)
Tank Storage

Pipeline

TankerLorry

4,000～5,000kcal/kg(4,800～6,000kcal/L)

Coal Concentration

60～70%

Density

1,200 kg/m3

Viscosity (25deg-C)

1,000 cp

Mean Particle Size

20 μm

資料435

5

Slurrification Technologies

資料436

6

JCF Production Process
LRC

HammerMill

Fuel

Filter Press
ReactorAdditives

Letdown
Valve

High Speed
Mixer

Ball Mill

Ball MillHP Slurry Pump
Recycle Water
資料437

Coal Slurry
7

Research and Development(1)1991-92
Autoclave

1992-1994
Continuous Bench Plant(3.0kg/h)

資料438

1995-1996
Pilot Plant(350kg-dry coal/h)8Research and Development(2)Autoclave (vessel volume:1L, 10L)

Pilot Plant (50kg-biomass/h)
Bench Plant (1kg-biomass/h)

資料439

9

Upgrading Test Result

資料440

10

Effect of HWT on CS Concentration

資料441

11

Combustion Test Results

Efficiency

SO2

資料442

12

Indonesian Coal Resources

Kalimantan

Production : 300Million tons/ySumatra（Export : 220Million tons/y）40 billion tons

57%

52 billion tons

Lignite·93billion tons

Low Rank Coal
26%+57%=83%

·

26%

·
·

(Water=30%~ )·

16%

Sub-bituminous

Bituminuos(Water=20 ~ 30%)

1% Anthracite (Water=5 ~1310%)

資料443

13

Schedule
2009

2010

2011

2012

2013

2014

2015

Demonstration Plant(Capacity : 10,000 t/y)
- Construction- Operation
Commercial Plant(Capacity : 1 MMt/y)- Feasibility Study- Construction- Operation

資料444

14

Commercialization of JCF
Coal Data Base

Demonstration Plant

JCF Production

JCF Application
BoilerSteamEngineElectricity

JCF:JGC COAL FUEL

Low Rank Coal

(Future Plan)

Selection of
Candidate Coalfor Demo Plant

Gasification

Chemicals(Future Plan)

AutoclaveExperiment using
Indonesian LRC

JCF UserCombustion Test
資料445

15

Investigation of clean methanefrom coal resources

October 28, 2010
Osaka Gas Co.,Ltd.
資料446

Osaka Gas Corporate profile Started business operations in 1905
 Serving 6.9 million natural gas customers in the Kansai Region(27% Japan Gas market share in sales volume) Import 7.4 million tons of LNG annually

Natural gas service area
Kyoto

140 affiliated companies

Kobe Osaka
Osaka
Nara

 19,009 employees

Bay(Osaka Gas(5,477) + consolidated subsidiary companies)
Managing 58,570km of natural gas pipelines
Osaka

Osaka Gas An n u al LNG Import
7 ,3 2 0

8 ,0 0 0
5 ,8 4 0 2 8 0

Thousand ton

7 ,0 0 0
6 ,0 0 0120

5 ,0 0 0

3 ,5 0 0

4 ,0 0 0
3 ,0 0 0
2 ,0 0 0
1 ,0 0 00

1 ,8 4 0

60

670
340

300
750
800
860

Other
Oman
Qatar
Malaysia
Brunei
Australia
Indonesia

1 ,1 7 0
610
670
800
1 ,1 6 0630
1 ,2 1 0

2 ,4 3 0

3 ,0 1 0

2 ,6 3 0

1980

1990

2000

2007

FY

資料447

Tokyo

Effective use of coal resources
・Our business is based on Natural Gas value chain・Effective use as Methane extracted from abundantcoal resources1)Development of Coal Mine Methane（CMM）
Concentration Technology2)Production of Substitute Natural Gas fromlow rank coal
資料448

Present situation of CMM Emissions
Worldwide CMM emissions converted into CO2 are estimatedas much as 380 million t-CO2 per year.
Rest oftheworld,
145.0

China,
117.6

USA,
56.2

Ukraine,28.3

Russia,29.0

Fig. Worldwide CMM emissions (converted into CO2)
（Reference：EPA）
資料449

Concept of CMM concentration system
Our system enables to concentrate CMM emitted to theatmosphere without any effective utilization.
Oxygen,Nitrogen
Adsorption tower
using methaneselective adsorbent

Product gas
Methane concentration:
40% or more

Vacuumpump

ProducttankElectricity supply

Gas engine-driven generator
Heat supply
Gas boiler

CMM
Methane concentration:
30% or lessPrevention of blowout
into excavating front
through preliminary
extraction

Emission to theatmosphere
CMM with a methane concentration
below 30% is emitted to the atmospherewithout any effective usage.
Methane gas
資料450

Coal

Excavating frontCMM Concentration Technology
Our system adopts the vacuum pressure swing adsorption(VPSA) technology using a high methane-selective adsorbent
developed by Osaka Gas.

Raw material gas

資料451

Concentrated gas

Demonstration Test : Site information
阜新市【Implementation term】

Fuxin

Shenyang2009. January～February【Site Information】
Location

Fuxin City
in northeastern China

Population

About 1.9 million

Latitudenorthern latitude of
41.5～42.5 degrees

Temperature

yearly average：8.7℃
minimum：-32.3℃
maximum：37.7℃

瀋陽市

資料452

Demonstration Test : Specifications
Specifications of CMM Concentration Plant for
Demonstration Test
• Inlet CMM

CH4: 20%
1,000 m3/hr• Product gas

CH4: 45%
400 m3/hr• Recovery factor 90% or higher
資料453

Demonstration Test : Plant appearance

Mixing tank
Adsorption
tower

Vacuum pump

資料454

9

Demonstration Test : Results
It was confirmed that CMM of 21% methane gas
was successfully concentrated to 48%.

資料455

Demonstration Test :Results

60
55

Methane recovery rate (%)

Methane concentration in product gas (%)

The target performance of our system was achieved (25%concentration, 90% recovery).

50
45

Raw material gas flow rate: 1,000 Nm3/h

40
15

20

25

30

Raw gas flow rate:1,000 Nm3/h

35

Methane concentration in raw material gas (%)

Methane concentration in raw material gas (%)

Fig.1 Dependence of the methane
concentration in raw material gas against
methane concentration in product gas

Fig.2 Dependence of the methane
concentration in raw material gas
against methane recovery rate

資料456

Effects of Introduction
For example,
if the commercial plant of CMM concentration (flowrate : 2,000Nm3/h) is installed;• Energy conservation: 2,600 kl/yr reduction(crude oil equivalent)• Greenhouse gases: 38,000 t/yr reduction(CO2 equivalent)

資料457

Expansion of applications of CMM
Auxiliary
air forcombustion

Electricity

Electricity

Lowconcentration
gas power
generation

Mediumconcentration
gas power
generation

Town
gas

LNG

Industrial
utilitygas

LNG
liquefier

Industrialrawmaterial
gas

Mediumconcentration
CMM
Ultra-lowConcentration
VAM

LowConcentration
CMM

Explosive
limit zone

0％

5％

10％

CMM
Concentration
System

CNG

HighConcentration
CMM

CMM
Concentration
SystemThe Concentration of Methane in CMM
20％

15％

30％

40％

50％

資料458

60％

70％

80％

90％

100％

2)Production of Substitute Natural Gas fromlow rank coal

資料459

Why Coal-to-LNG ?
Conventional LNG market

Reserve/Production Ratio
133ｙ

85ｙ
60ｙ
42ｙ

LNG Consumption Growth

Petroleum

Natural Gas

Uranium

Coal

Coal to LNG market

BP Statistical review of world Energy

S-LNG from low rank coal has apotential to realize a flat energy price.
25.00

ＬＮＧ CIF Japan

Thermal Coal CIF in Japan
10.00

20
09

20
08

Indonesia Low rank coal
FOB（4220kcal/kg)

20
07

0.00

20
06

Australia Thermal coal
FOB(6322kcal/kg)

20
05

5.00

20
04

$/MMBTULNG CIF in Japan
15.00

資料460

LNG CIF （$/MMBTU）

JCC
20.00

S-LNG CIF

JCC CIF（＄／bbl）

Concept and Process Flow
Natural gas and LNG can be produced from abundant low-rankcoal to compensate for both local and international demand.
Shift Reaction
H2O + CO ⇆ H2 + CO2

Syngas
H2、CO、CO2、CH4

Shiftreactor

Coal

Acid gas
removalO2

Low rank coal

Steam

Acid gas removal
・CO2, H2S

Methanation
CO + 3H2 ⇆ CH4 + H2O
CO2 + 4H2 ⇆ CH4 + 2H2O
Comp.

ash

LNG

cooling( Long transport)

Methanator

Gasifier

SNG

SulfurCO2

LNG Plant

SNG(Local distribution)

EOR

CCS

Gasification of low-rank-coal with CO2 sequestration can
produce low-carbon fuel like natural gas.
資料461

Site selection for Coal-to-SNG in mine mouth
Case(Case1 )SNG in mine mouth to LNG
plant , LNG to long transport(Case2)
SNG in mine mouth to pipeline,
swap LNG to long transport

Requirement 1

LNG plant which has enoughcapacity to liquefy SNG

Gas pipeline which has enoughcapacity to transport SNG

Gas Infrastructure

Requirement 2
Low rank coalSufficient quantities of reasonable low rank coal which can beeasily gasified(sub-bituminous or lignite : 3-6Mt/y for 20-25 years)

Requirement 3

EOR/CCS sites into which CO2 from SNG plant can be injected

CO2 management

Requirement 4
Other

Sufficient quantities of water which can be used for gasification(10-15Mt/y)
CO2

EOR or CCS
Gas pipeline

Low rank coal

SNG plant
in mine mouth

SNG

LNG Plant
資料462

Potential Plant sites in East Kalimantan
Indonesia (East Kalimantan)

Potential Plant Area

A Coal Mine

Hauling Road (Planned)
Feasibility study of
CO2－EORB Coal Mine

Bargetransportation
Mahakam Riverdownstream basin

Oil & Gas field

C Coal Mine
資料463

Gas pipelineLNG Production at PT Badak

資料464

LNG Plant Process Flow・Most Impurities (CO2, H2O, Hg, H2) can be removed in the existing
pretreatment process of LNG Plant
・Some modifications in the Flash drum might be required to remove N2 and Ar.

Flush Drum

資料465

Mass Flow Diagram of Gasification from Lignite
Steam

3

Steam

340℃

CO Shift

300℃

Coal

2

Sour Shift1

Gasification

Coal

4

Methanation

5

SNG

6

Heat recovery

6000ton-dry/day

Coal
Preparation

Acid gas
removal103,000Nm3/h
0.59MM t/yasCH4@8000hr/y

1.7MPaG

ASU

sulfur12ton/day

CO2

7

3.6MPaG

O2

1

2

3

4

5

6

7

OxygenOutlet of
Gasifier

Steam forＣＯ
shift

Steam for
Methanation

Inlet of
Methanation

SNG

CO2

Stream No.

10,000ton/day

Flow rate

Kgmol/h

6800

24500

8500

8500

19300

5440

9470

H2

mole%

0.0

25.3

0.0

0.0

71.9

1.9

0.0

O2

mole%

93.8

0.0

0.0

0.0

0.0

0.0

0.0

N2

mole%

6.23

2.1

0.0

0.0

2.6

9.3

0.0

CO

mole%

0.0

50.0

0.0

0.0

23.9

300ppm

0.0

CO2

mole%

0.0

8.3

0.0

0.0

1.0

3.9

100.0

CH4

mole%

0.0

0.04

0.0

0.0

0.05

84.4

0.0

H2S

mole%

0.0

0.06

0.0

0.0

0.0

0.0

0.0

H2O

mole%

0.0

14.3

100.0

100.0

0.5

0.4

0.0

資料466

Source: Study report about Coal to SNG, METI, 2008

Cost estimation of substitute LNG
LNG CIF（Japan）

25.00

25

20.00

20

15.00

15

$/MMBtu$/MMBtu

Substitute LNG Production cost

10.00

10

5

5.00

0

0.00
En t r ain e d be d inJapan

En t r ain e d be d in
In do n e sia

1988 1989 1991 1993 1995 1997 1999 2001 2003 2005 2007 2009 2011

Fixe d be d in
In do n e sia

Others8%
De pre c iation
31%

Maintenance
22%

Coal
39%

Depreciation term: 20years
Coal price: $30/t
資料467

Source: Study report about Coal to SNG, METI, 2008

Summary
Evaluation Items

Result of preliminary study① Suitable gasification
technology andmethanation technology
for SNG・There are some commercial technologies for
producing SNG from low-rank-coal.
・Advanced technologies using low-rank-coal will
improve economics.

② Possibility of utilizing
the existing gas
infrastructures (Pipeline
and LNG plant)

・Effective utilization of the existing gas
infrastructures for SNG is expected because theconventional gas production has been decreasing.

③ Availability of cheap
low-rank-coal・There seem to be some suitable low-rank-coalresources for SNG production in East Kalimantan.
・Less competitiveness based on the existing coalprice index.

④ Economics of SNG

・Estimated SNG costs are expected to becompetitive under the circumstances of high
LNG price.

⑤ Potential of CO2-EOR
and CCS・Some studies have been already conducted,
資料468
however no detailed evaluation was conducted.

Future Subjects
Key issues for evaluation of new business１．Detailed investigation of CO2 sequestration
Detailed evaluation of specified potential CO2 reservoir(EOR, CCS, ECBM)
２．Detailed investigation of Low-rank-coal resources
Geological survey of low-rank and low-cost-mining coalresources
３．Feasibility study of co-production case
SNG, ammonia, methanol, power generation
４．Laws and regulations
Coal Price Index for low-rank-coal、DMO for gasification
product
資料469

(10)セッション 4A(ii)

資料470

Coal Upgrading Technologies
By : Jeffrey Mulyono

資料471

Case study BEP:
Why Need to Upgrade
BEP Coal Upgraded Quality

BEP Coal Quality
CV (AR)

3450 – 3500 Kcal/Kg

TM (AR)

45 – 46 %Sulphur(AR)< 0.14%

CV (AR)

5600 Kcal/Kg

TM (AR)

11 %Sulphur(AR)< 0.17%

Coal
Upgrading

PLN - Power Plant Coal
Specification

資料472

Caloric Value(AR)

3900 – 6000
Kcal/kg

TM (AR)< 35%

Sulphur (AR)0.33 %

Upgrading Coal Technologies• Binderless Coal Briquetting (BCB) Technology;
The crushed coal is injected into a drying column where it come into direct contact with the hot gas from thefurnace, essentially driving off the water in the coal. The dried coal is briquetted without binder• Upgraded Brown Coal (UBC) Technology
Multi stage process involving pulverizing the brown coal, mixing it with oil, heating the mixture using steam todrive out the moisture and then recovering oil and cleaning up the water• K-Fuel Technology
Moisture of Brown coal is driven off by using high temperature and high pressurized vessel that is held at about
40 bar and 250 0C and the process it self will change the basic behaviour of the coal

• GTL Energy
Low temperature drying process• Coal Upgrading-Briquetting (CUB)
The process is based on the principle of evaporative drying by using a flash dryer to vaporize the moisture out of
the coal. And used of the double cone briquetting machine to compress the coal into an egg shape block(briquette).
資料473

Upgrading Coal Technologies
Some others upgrading coal technologies worth to mention are:

•
•
•
•
•
•
•
•
•

Nu-Fuel Technology
Lignite Fuel Enhancement System
Steam Fluidized Bed Drying, WTA Technology
Coal Depolymerisation
Coldry Technology
Continuous Hydrothermal Drying Technology
Mechanical Thermal Expression
Syncoal Technology
FXL Energy

資料474

APEC Clean Fossil Energy Technical and Policy Seminar 2010

Twin IHI Gasifier(TIGAR®) Technology
for Chemical Feedstock
TIGAR:Twin Ihi GAsifieR
28th October, 2010

※TIGAR® is under development.

Power Plant Division

資料475
Copyright © 2010 IHI Corporation All Rights Reserved.
Copying is prohibited.

IHI coal gasification technology TIGAR®

FluegasSyngas

Fuel
Steam
Air
Combustor

Gasifier

Circulating fluidized bed gasifiersystem– Bubbling fluidized bed gasifier– Circulating fluidized bed (CFB)
combustor– Complete seal of gas
Gasifier– Steam blown gasifier– VM and part of char gasified– High calorific gas (Nocontamination of air)
Combustor– Air blown combustor– Char combustion
Operate under atmospheric pressure
資料476

Copying is prohibited.

Components of TIGAR®
■ Components of TIGAR® are combined mature CFB and BFB technology.
Circulating Fluidizing Bed (CFB)

Bubbling Fluidized Bed (BFB)
BubbleParticles

資料477
Copying is prohibited.

Applications of TIGAR®

CO, H2CO, H2

Shift reaction

Products

Application

CO,H2(Synthesis gas)

GT,GE fuelDirect Reduction
Iron Manufacture

H2

Fuel cell
Ammonia (NH3)H2 for direct CTL

CH4

Substitute
Natural Gas

CO2CO, H2Coal

Synthesis

Biomass
Waste

CTL

CO, H2

Gasifier

Synthesis

DME
Methanol

TIGAR® can be used for many applications.
資料478
Copying is prohibited.

gasliquidAutomobile fuelChemicalRaw Material

Available feedstock of “TIGAR®”■ Easy utilization of Coal and Biomass feedstock
because of operating under atmospheric pressure■ Simple feeding system to gasifier

Easy CO2 Reduction

Available Feedstock

Wood

BagasseCoal (LRC)

Bark

Palm Waste

資料479
Copying is prohibited.

Steam gasification of lignite

Carbon conversion [mol/mol]■ Lignite can be easily gasified.
1.0
0.9
0.8
0.7
0.6
0.5
0.4
0.3
0.2
0.1
0.0

Bituminous
Lignite010Sub-bituminous

20

Gasification time [min.]Steam gasificationin lab. fluidized bed reactor(0.1MPa, 900degC)
資料480
Copying is prohibited.

30• Lignite steam
gasification isfaster thanbituminous coal
• Steam gasification
is suitable forligniteComparison of gasifier

Gasification
Process

TIGAR

Type T

Type S

Gasifier type

Fluidized bed

Entrained bed

Entrained bed Moving bed

Operation press.

0.1-0.5MPa>3MPa> 3MPa

1-3 MPa

Operation Temp.

800-1,000>1,400>1,500

1,200

Steam

OxygenOxygenOxygenHigh availability

SlurryPowderBulk

ResidueDry ash

Slug

Slug

Dry ashEfficiency

High

Very low

Moderate

Low

Oxidizer
Coal Feeding

Type L(for lignite)

Low cost and Sim ple operation
資料481
Copying is prohibited.

Target of “TIGAR®”■ Applied class of capacity and feedstock
Low Volatile

Anthracite
Bituminous

Entrained bed typegasifier

Sub-bituminous

TIGAR®
Dry Feed
Entrained bed typegasifier

Low
Rank
Coal
and
Biomass

LigniteBiomass
Higher Volatile

300t/d1000t/d
資料482
Capacity/ 1 unit

Copying is prohibited.

2000t/dFeatures of TIGAR®
■ TIGAR® is suitable technology to use Indonesian low rank coal.

•

Lower CAPEX and simple Operation & Maintenance– Lower pressure and lower temperature in operating condition– Small air separation unit (oxygen plant)•High reliability and availability– Based on mature fluidized bed technologies•

Multi-fuel application– Low rank coal, biomass and theirco-utilization•

Co-production– Variable change of ratio ofsyngas to power generation

3000t/d Coal gasification plant image
資料483
Copying is prohibited.

Development schedule
FY
2004

At present

2005

2006

2007

2008

2009

2010

2011

2012

2013

2014

2015
CONFIDENTIAL

3D view of TIGAR R (Prototype Plant 50t/day)

TIGAR R

Bench scale facility
testing

Simulation andsmall scale
facility testing

FL 36mPilot Plant stage

FL 23mGasifie r
HRA for Gasifier
HRA for Combustor
GAH

Coal storage yard
Ash and Sand storage yard

Coal conveyer

Bag filter
Settling pond

FL 13m

LPG tank
Control Room

Incinerator

FDF

Cooling Tower

FL 0m
BFP

G-IDF
Buffer tankGas cooler

50t/d

Cooling water pump

PRELIMINARY

Prototype Plant stage

0.1t/dNow Planning@ Indonesia
6t/d@ IHI Yokohama

Laboratory scale
gasification
facility

資料484
Copying is prohibited.

Combu stor

300~1000t/d
Commercial
Plant

6t/d Pilot Plant■ Confirmation of TIGARⓇ technology with full process~2008 Gasification test with TIGARⓇ~2009 Modification
2010~ Official tests

Gasification area

Modified/ Additional
Area

Gasification
Gas

B agf ilt er

c ooler

Waste Water
treatment area

S t ac k
FanCoalbunk er

Cy c lone
Conv ey er
Combus t or

Gas cleanup

HopperRef ormer

S and

Flare

Feeders t ac k

Gas if ier

Fan
A ir

S t eamFan
B oilerTar dec ant er

Waste Water treatment
資料485

Copying is prohibited.

Gas Clean up areaPerformance of 6t/d Pilot Plant■ Gasification performance of lignite■ H2 rich syngas has broad utilization.

Carbon Conversion

is higher than its of sub-bituminous.

LigniteCH49%Sub-bituminous

CO2
19%

Other HC
3%

H2
51%

H2
CO
CO2
CH4
Other HC

CO
18%

Tg
Carbon Conversion
vs. Gasifier Temperature

Gas Compositions(N2 < 1%)
資料486

Copying is prohibited.

Operation of 6t/d Pilot Plant■ Lignite and sub-bituminous coals show stable gasification
performance.
Load
Combustor temp.
Gasifier temp.
Cold gas efficiency
Carbon conversion

0
Copying is prohibited.

20

40

60

80
100 120 140
Operation
資料487 time [min]

160

180

Future plan – Indonesia energy aspect■ Indonesia has big amount of resources of Row Lank Coal.
■ Indonesia has also big amount of resources of Natural gas.
■ The demand for Natural Gas is in particular big by the fertilizer industry.
Coal

Natural Gas
0.5%4%(90)1.1%(306) 2%(150) (39)

4%
(310)
6%
(464)
7%
(562)

Policy of Indonesia energy supply
Sub bituminous

Anthracite
0.3%

Fertilizer

26.7%

49%
(3935)

11%(884)

Export

11%
(914)
5%
(443)

Lignite58.7%

Bituminous
14.3%
Indonesia Coal Resources

Total：8,095.5MMSCF
Natural gas
consumption in Indonesia(2006,MMSCFD)For Indonesia, gasification of LRC as the backup of Natural Gas is required.
For Japan also, gasification of LRC contributes to energy security.
資料488

Copying is prohibited.

Future plan – apply to the existing fertiliser plant■ IHI studied feasibility of TIGAR® applying existing fertilizer plant
NaturalGas

ReformerLigniteGasifier
TIGAR

Ammonia
Process

Change!

Pupuk Iskandar
Muda
Ammonia 762
Urea
1170

Pupuk Kalimantan Timur
Ammonia 1848
Urea
2980

Pupuk Sriwidjaja
Ammonia 1499
Urea
2262

Pupuk Kujang
Ammonia 713
Urea
1156

PUSRI group
Fertilizer plant
Capacity 1,000t/y（2008 Pusri Annual Report）

Petrokimia
GresikAmmonia 445.5
Urea
462
資料489

Copying is prohibited.

Urea
Process

Summary• Twin IHI Gasifier (TIGAR®) is being developed for lignite
gasification.
• TIGAR® can stably produce syngas with higher heating value from
Lignite coal.
• 6t/d Pilot Plant test indicated that TIGAR ® system is proventechnology for lignite gasification.
• CO2 can be captured from syngas using coal gasification, and
TIGAR® can utilize the biomass as feed stock easily, so can
suppress the production of the CO2.
• We are planning to apply TIGAR® to Indonesian fertilizer plant as
the first step of the commercial stage.

資料490
Copying is prohibited.

Thank you!

資料491
Copying is prohibited.

Future Perspectiveof Low Rank Coal Utilization

October 28, 2010
New Energy and Industrial Technology Development Organization

資料492

Coal Reserves and Role of Low Rank Coal
☆ The stability of coal supply is higher than that of other fossil fuels?
☆ Low rank coal, that has lower value as an exporting commodity and ismainly used in mine-mouth power generation , should have more
important role.
role
150
122

R/P ratio
100826
billiontonnes

60.4
50

0

42.0
1,258
1
258
billionbarrels

185
trillion
cubic
metresOilNatural Gas

R/P[Years]■Oil ■NG

■Coal

Coal

Reserve-Production Ratio of Fossil Fuels

Lignite
150 B tonnes
18%
Bituminous
including826
Anthracite
billion tonnes 411 B tonnes
50%

Ref. : BP “Statistical Review of World Energy 2002-2009”Sub-bituminous
265 B tonnes
32%

Trend of R/P Ratio of Coal
Recoverable Reserves by Coal Type

2

資料493

Role of Coal in World’s Energy Balance☆ The share of coal accounts for one-quarter of total primary energy supply in theworld and its consumption is expected to achieve a 1.5 fold increases in 2030.
☆ Coal fired power generation represents 40% of total volume generated in the world
and is projected to doubled in 2030.
Primary Energy Demand by Fuel: WorldPower Generation Mix by Fuel: World
35,000

Renewable
Hydro
Nuclear
Gas
Oil
Coal

発電電力量（TWh）

30,00020,00015,000
10 00010,000

１.５
times

２７％

25,000

２９％

5,000

10%

20%

50%

60%

70%

United States

24%

Japan

22%

24%

Germany

35%

18%

Oil

32.6%

Gas

34%

Nuclear

16%
25%

31.5%

27%

World Total

1.8%
0.7%
23%

39%

26%

United Kingdom

6%

45%

19%

EU

80%
18%

41%

India

Source:

40%

66%

China

Coal

30%

Hydro

2000

2010

2020

2030

Source: IEA,
IEA “World
World Energy Outlook 2009”
2009

Composition of Primary Energy Consumption in Major Countries (2007)
0%

４２％

0
1990

Source: IEA, “World Energy Outlook 2009”４４％

2 times

90%
3% 2.1% 10%
0.8%
27%

Composition of Power Generation Mix in Major Countries (2007)

100%

0%

0.3%

0.8%

23%

11% 0.5% 7%

39%
21%

8%
0.4%
0.2% 2%6% 2.2% 10%
0.6%

Biomass

Other Renewable

IEA, "World Energy Outlook 2009"& "Energy Balances of OECD Countries (2009 Edition)"
資料494

20%

30%

40%

60%

68%

I di
India
49%

United States
Japan

28%

EU

31%

70%

80%

35%

United Kingdom

1.7%
1.2%

42%

World Total

Oil

Source:Gas

Nuclear

19%

21%

24%
28%

22%

49%

8%

26%

14%

11%

9%

22%

42%
6%

21%

Hydro

Wind

90%

100%

1.0% 1.9% 15%
1.2%
2 1% 16%
2.1%

5%
1.8%

3.4%

Germany

Coal

50%

81%

China

0.3%

9% 0.9% 0.6%
4%
13% 1.2% 0.8%
1%14%
1.5% 6% 0.9%

10%

14%

Solar

0.1%

0 0%
0.0%
1.5%
6%
2%
0.8%
2%
7%
0.3%
3.1% 3%

4% 6.2% 5%
0 5%
0.5%
16%
2% 3%
1.3%
2%
16%
0.9%

Other Renewables

IEA, "World Energy Outlook 2009"& "Electricity information 2009"3

Varieties of Low Rank Coal
☆ High ash and high moisture content coal are generally defied as low
rank coal.
☆ High moisture content coal usually has spontaneous combustion
properties when dried.
dried These properties make it difficult fortransportation.

Coal Rank and Properties of Coal
LigniteSubbitumino
usBituminous

AnthraciteCoal Rank

Low

Heating
Value(kcal/kg)

2,500～
4,000

4,000～
6,000

4,500～
7,000

4,500～
8,000

Moisture(%)

60～30

30～15

Less
than 15

Less
than 10

High

4

資料495

Refining Technologies of Low Rank Coal
☆ Low rank coal can be converted to various products similar to high rank
coal. Technologies for high ash content or high moisture content are
particular to low rank coal.
Technology

Low Rank
Coal

Unit / Process

Products

De-ashing / De-mineralization- Variwave Jig- Hyperyp Coal Technologygy- De-ashed coal
- Ash-free coal
- Cokes binder

De-wateringg / Slurrification- UBC- HWT-CWM
HWT CWM- Upgraded brown coal
- Hot water treating coal water mixture

Gasification- EAGLE (entrained flow gasifier)- ECOPRO- Tigar (fluidized bed gasifier)- Synthesis gas (H2 + CO)- Hydrogen (via shift reaction)

Liquefaction- Direct coal liquefaction (NEDOL(NEDOL, BCL)
- Indirect coal liquefaction- Gasoline / kerosene / gas oil- FT product / methanol / DME etc.

- Carbonization briquetting- Bio-briquetting- Coke making- Char / cokes / activated carbon- Briquette

Coking5

資料496

Refining Technologies of Low Rank Coal((Variwave Jig
g Unit))Variable Wave
Pattern

Automatic Discharging
RejectjControl
SystemPLC
VVVF

BED HIGHT DETECTORSLIDE GATE MOTER

EXHAUST
Hi
Hi-press
BLOWER

FLOAT

VALVE
2nd VSSL.

1st VSSL.

MOTOR

COMPUTER

No. of unit installed by country
JIG

Low-press BLOWER

資料497

Country

No. of unit

Japan

5

China

1

Vietnam1

Indonesia

1

India

1(2011.3)

6

Refining Technologies of Low Rank Coal((Hyperyp Coal Technology)gy)☆ Hyper coal technology can produce ash-less coal (less than 200ppm).

Hyper Coal
Solublematter

H Coal
Hyper
C l

Ash

Solid/Liquid
separation
Solvent recovery

HeatingIInsoluble
l blmatterCoal

Solvent

I l bl CCoall
Insoluble(Byproduct)

Coal is mixed withorganic solvent and thecoal
structureslurryis heated.

Coal structure is relaxedby the solvent and organicisparts of coal are dissolvedd and dissolving
in the solvent.

After extraction,, thesolubles (Hyper Coal)and residue(insolubles & ash) are
separated.
td
0.1t/d BSU
7

資料498

Refining Technologies of Low Rank Coal((UBC Process))☆ Heating value of upgraded brown coal is around 6,500kcal/kg, and its
spontaneous combustion problem is also suppressed.

UBC Process

600 t/d D
Demonstrationt ti Pl
PlanttUBC briquette

8

資料499

Refining Technologies of Low Rank Coal((HWT-CWM Process))☆ Internal water in low rank coal is extracted by hot water without
evaporating. Inner surface properties are changed from hydrophilic tohydrophobic by deposition of tar.
☆ Stable coal water mixture can be produced.

Mechanism of hot water treatment

Coal water mixture

9

資料500

Refining Technologies of Low Rank Coal((Eagleg Coal Gasification Technology)gy)☆ Eagle coal gasification technology has been established by 150t/d PP.
☆ CO2 capturep(amine(absorption)p) technology
gy was also demonstrated.
Facility : EAGLE Pilot Plant (150 tons/day)

Gasifier(150 tons/day)
Air separation
facilities

Incinerator

CO2 separation &recovery facilities

Gas purifier

Sulfur recovery
facilities

Gas turbine house(8 MW)EAGLE (Coal Energy Application for Gas, Liquid & Electricity)

Located in J-Power’s Wakamatsu Laboratory
資料501

10

Zero Emission Coal Complex
De-watering

PCF
BoilerElectricity / SteamSlurrification

Heavy Oil
BoilerElectricity / Steam

Gasification

Gas
Cleaning
CO2

Syngas

IGCC
Plant

Electricity

Shaft
Furnace

Pig Iron

SNG
Plant

Storage

Methanol
Plant

Low Rank
Coal

Hydrogen
Plant

LNG
Plant

LNG

Methanol
MTG
Plant

Gasoline

DME/MTO Plant

DME / Olefin
HydrogenAmmonia
Plant

Ammonia / Urea

Oil
RefineryOil products

Liquefaction

Oil products

CokingSolid FuelBlast Furnace
11

資料502

Examples of Zero Emission Coal Complex

East Kalimantan
Methanol, Chemical Plant
Ammonia, Urea

Gas Field
Syngas ／Hydrogen

Methanol, DME
G li PP,
Gasoline
PP Acetic
A ti Acid
A id
Ammonia, Urea

MethanePipeline

Chemical Plant

MethanolM
th l
DME, Gasoline,
PP, Acetic Acid

Shipping

SNG

Low Rank Coal

CO／H2
Gasifier

Methanol

LNG（PT Badak)

H2
CO2
Storage

Already Installed
Newly Installed

SyngasAmmonia

G Power
Gas
P（34MW KDM)
（34MW、KDM)

Shipping

Urea Plant
Ammonia,, Urea

Shipping

Electricity

12

資料503

Conclusion

Keyword for Using Low Rank Coal

Improving Efficiency
Zero-emission
SustainabilityyEconomically
y
13

資料504

(11) セッション 4B(i)

資料505

2010 APEC Clean Fossil Energy
Technical and Policy Seminar
Fukuoka, Japan

Current Status of CCS R&D
in JapanOct. 28, 2010

Masato Takagi
Research Institute of Innovative
Technology for the Earth (RITE)
資料506

Contents
1. CCS Status in Japan
2. Capture Technology Development
3. Geological Storage Development
4. Large-scale Demonstration andFeasibility Study
5. International Cooperation
資料507

1. CCS Status: Roadmap

CaptureStorage

資料508

Challenges for CCS
Capture: Cost and energy cutting,new solvent, sorbent, and membrane
Storage: Technologies for safe storage, regulations,public awarenessLarge-scale Demonstration:
Site selection, detailed characterization ofcandidate sites, design of facilities,
feasibility study, construction, and injection
資料509

2. Capture Technology Development
 Current Cost:– 4,200 yen per ton was estimated for new pulverized coal powerplant Target Cost:– 2,000 yen per ton by around 2015
– 1,000 yen or so in the 2020s(Membrane on high-pressured gas)

 Technologies:– Post Combustion: chemical absorption (MHI, RITE, Toshiba)– Pre Combustion: physical and chemical absorption, membrane– Oxy Fuel: test in Callide A

資料510

Chemical Absorption Solvent
New solvents for Post Combustion have been developed andare being tested in pilot scale.
For Cole Power:•MHI KS-1:10t/d→500t/d•Toshiba: 10t/d

MHI
Matsushima 10t/d

For Iron & Steel making•RITE-Nippon steel:
1t/d →30t/d

資料511
Toshiba
Ohmuta 10t/d

RITE-Nippon steel
Kimitsu 30t/d

Estimation of solvent performance
Improvement in heat efficiency by scale-up

Regeneration energy [GJ/t-CO2]

5.0

1 t/d plant
Experiment3,000 t/d
Estimation

4.0
3.3
3.0

2.65

系列4
Others (heat loss, etc)
系列3
Vapor from stripper top
系列2
Sensible heat of solvent
系列1
Reaction heat

3.1
2.5

Target2.0

Steam generated
from waste heat:

1.0

1,500 JPY/ kg-steam
0.0(exp.)(est.)(exp.)

Solvent C

RITE-5(est.)

Solvent D
資料512

RITE-6

Capture cost
3,000 JPY/ t-CO2

Membrane

資料513

CO2 separation performanceof dense films and the goal
Thickness：500μm ⇒Thinner？
50

CO/H/H selectivityCO
2 2 22selectivity (-)

RITE
40

× 50-

9
7

30

6
4
2

3

8

1

10

Science

10

-13

10

11

Goal

5

20

0
-14
10

100

10

35℃

-12

10
3

(1)

-11

10

-10

10

-9

2

3
m (STP)/(ms Pa)2
COPermeance,
2 permeance / m (STP)/(m s Pa)
資料514(1) H. Lin B.Freeman et al., Science, 311, 639-642 (2006).

Development of Membrane module-Cooperation with private companiesCooperation with
Four membrane companies (Kuraray, Daicel, Toray, Nitto-Denko)
Engineering company (Nippon Steel Engineering)
Dendrimer/
Polymeric matrix

500μｍ

10μｍ

3μｍ

Hollow-fiber membranes + ＰＥＧＤＭＡ/ＴＭＰＴＭＡ
matrix
資料515

3. Geological Storage Development
 Storage Capacity Estimation:• Many aquifers and some depleted oil/gas reservoirs were
investigated for a CO2 storage reservoir (RITE)– Anticline: 30 billion and Geologic structure without anticline:116
billion• Detailed site characterization of candidate sites for large
scale demonstration are being conducted (JCCS).

 Nagaoka Project• 10,000 tons of CO2 were injected into a deep saline
aquifer and various kinds of monitoring were applied to
identify CO2 migration and distribution (RITE).
• Those monitoring is ongoing now.
資料516

Potential Storage Sites in Japan●Estimated storage capacity in Japan： 5.2 – 146 billion t●Need more detailed investigations of reservoirs for large scaledemonstrations.

資料517

Nagaoka Project
Injection well

Nagaoka Site

Nagaoka city
Tokyo

RITE (Kyoto)

Hiroshima
CO2 storage tank

1000m
2000m

CO2 injection pump
Evaporator

5000m

Target depth 1100 m
CO2 injection well

資料518

Gas production from 4500 m depthNagaoka Project[Pilot test overview]
CO2 injection period

Jul. 2003 to Jan. 2005

CO2 injected amountabout 10,400 t-CO2[Well configuration]
Observation well 4
Logging

60 m

CO2 injection rate

20 to 40 t-CO2/day

CO2 source

purchased commercial CO2

Monitoring

well logging, crosswell seismic
tomography, microseismicity,formation water sampling, etc.

[CO2 monitoring by crosswellseismic tomography]

Observation well 3

Observation well

Logging

120 m

Observation well 2
40 m
Logging

Injection well 1[Outline of injection experiment ]CO2 storage tankTransport
Evaporato
tanker lorryr
Pump

Injection well

Caｐ layer：
about 140 m

Depth：about 1,100 m

Cap rock

Saline aquifer：
about 60 m

Saline aquifer

CO2

資料519

CO2

Injection layer ：about 12 m
Inclination ：１５°

Geophysical and Geochemical
Monitoring

8th

39th

PlanedRate; 20~40 ton/day
Total; 10,400 ton

資料520

Cumulative amount(t-CO2/day)

Injection Rate
(t-CO2/day)Seismic
tomography
Well Loggings- Neutron OB-2
OB-3
- Sonic- Induction OB-4
Fluid
Sampling

Solubility trapping image by resistivity
Post-injection(%)

Without free CO230
25

Depth (mMD)

1108

Injection

20
15
10
5
0
-5
-10

1112

1116

1120
0

500

1000
1500
2000
Elapsed time (day)Free CO2
Dissolved CO2 (HCO3-)

資料521

2500

4. Large-scale Demonstration
and Feasibility Study JAPAN CCS Co., Ltd. was incorporated in 2008 and isconducting site selection, site characterization, design offacilities, and feasibility study for large-scale demonstrationin around 2012. (JCCS is a private company founded byinvestment of 37 private companies for a comprehensive
investigation for CCS projects in Japan)
 Innovative Zero-emission Coal Gasification Power
Generation Project： NEDO is conducting feasibility study onsome full CCS cases• three IGCC sites – three storage sites• capture from IGCC, transportation (pipeline or ship), and storage inaquifer• conceptual design and cost analysis
資料522

CCS Demonstration Project Phase
Fiscal Year
2008

09

10

Investigation Phase

11

12 Demonstration Phase

METI
Development of Assessment Technologies
Subsidized
and Site Screening for Large-scale CCS Demonstrations
Project

METI Commissioned Project“Demonstration of CO2 Reduction Technology”

NEDO Commissioned ProjectjCCS

Feasibility Study – CCS Total System
CO2 capture at IGCC and store
at an offshore depleted gas field
資料523*Fiscal Year : April - March
TodayCandidate sites for CCS demonstrations“ JCCS is conducting investigation and studies on three candidate sites
for CCS demonstration ”

Site

Reservoir Type

CO2
SourceTransportation

Current status

Iwaki-oki

Depleted oil and gas
field

IGCC

Offshorepipeline

1) Geological modeling andsimulation

Tomakomai

KitaKyushu

Saline aquifer withclosureSaline aquifer without
closure (Neogene)

OilrefinerySaline aquifer without
closure (Palaeogene)

Preliminary survey (boring)

資料524

jCCS

1) Seismic survey
Onshore2) Geological modeling andpipeline andsimulation
tank trucks3) Survey well

CO2 Geological Storage-Potential Storage Sites in Japan●Estimated storage capacity in Japan： 5.2 – 146 billion t●Need more detailed investigations of reservoirs for large scaledemonstrations.

Tomakomai

Nagaoka
Kita-kyusyu

Iwaki-oki
資料525

Innovative Zero-emission Coal Gasification
Power Generation Project
Feasibility study （on total system from power generation to CCS）
(1) Coal ｇasification Capture/Storage/ power generation• System design
Ｈ2
CO
＋Ｈ2

Coal gasification

CO2
＋Ｈ2

CO2
separation/
capture(3) Storage(2) Transport

TurbineMarine transport

Geological storage
Storage unit

CO2

Compressor Tank

Pump

Review a total system from power generation to CO2 storage(1) Concept design of CO2 separation and capture system(2) Concept design of CO2 transport system(3) Concept design of CO2 storage system and review of the potential of
CO2 storage(4) Review a total system from power generation to CO2 storage(5) Concept design of a total system
at a specified
資料526
site (Nakoso area)

5. International Cooperation
International Cooperation:
CSLF, IEA-GHG, GCCSI
Collaboration in R&D• US: Capture (RITE-NETL), Storage (RITE-LBNL,AIST-LANL) etc.
• Canada: Weyburn-Middale Monitoring Project,
Aquistore (RITE-PTRC)• Australia : Callide A, ZeroGen• China: CCS-EOR (RITE-Petro China)• Others: Indonesia
資料527

Conclusion●Major challenges for deployment of CCS in Japan
1．To investigate more reservoir candidates
2．To reduce CCS cost by half mainly by developing
innovative capture technologies
3. To formulate regulations and to increase PA●Japan has first-class individual technologies for CCS．
For better integration of those technologies, we areentering upon new phase of large-scaledemonstration.

資料528

Thank you for your attention !

GHGT11
Kyoto
November 2012

資料529

Overview and Status of CCS
Developments in Canada
Dr. Frank Mourits
Office of Energy Research and Development
Natural Resources Canada (NRCan)APEC Clean Fossil Energy Technical and Policy Seminar
Fukuoka, Japan, 26-28 October, 2010

資料530

Presentation Overview
 Background• Importance of CCS to Canada• Opportunities and Challenges

 Overview of Canada’s CCS Initiatives• Research, Development and Demonstration• Public Engagement and Knowledge Sharing• Legislation and Regulations• Collaboration with Domestic and International
Partners

 Summary
資料531

Background - Importance of CCSEnergy production is one of the cornerstones of theCanadian economy, but also leads to significant
GHG emissions



Canada has ambitious GHG reduction targets

Our challenge – reconciling an economicallyimportant energy sector with climate change
objectives



Carbon Capture and Storage (CCS) is one key
element to help balance Canada’s energy,
environmental and economic goals

資料532

Canada’s GHG Challenge
Committed to 17% reduction below 2005
by 2020 and 60-70% by 2050
900
850

Megatonnes

800
750

260 Mt700
650

17% below 2005 levels

600
550
2005

2010

2015

Business as usual emissions
Canada’s GHG Goals
資料533
Environment Canada, March 20102020

GHG reduction “wedges” for 20% reduction
by 2020 and 65% reduction by 2050
(National Round Table on the Environment and the Economy*)40%* From report: "Getting to 2050:資料534
Canada's Transition to a Low-Emission Future (Nov. 2007)"

Reducing GHG emissions in Canada
Federal GHG Targets and Measures Committed to 17% reduction below 2005 by 2020 and
60-70% by 2050 (aligned with U.S.) Committed to achieve 90% of electricity from nonemitting sources by 2020, which include fossil energybased plants with CCS
 Regulation to be introduced in 2011:

New coal-fired plants built after 2015 and units that havereached the end of their economic life must meetemission performance standard equivalent to Natural
Gas Combined Cycle (NGCC) technology (performanceof average coal-fired plant capturing 70% of its CO2
emissions)

CCS-ready coal plants to be exempted until 2025
資料535

Canada has a natural CCS advantage…
GHG Emissions (Mt CO2 Eq)

Canadian Arctic
Island Basin
BeaufortMackenzie
Basin

Baffin
Basin

NWT
&N
1

YK
1

Intramontane
BasinsPacific
BasinsBC
62

NF&L Labrador
1
BasinsWestern
CanadianAB
Sedimentary
234
Basin

Hudson Bay
Basins
SK
72

ON
190

MB
21

Gulf ofSt. QC
Laurence
Basins82
St. LaurenceRiver Basins

資料536–7– –7–

Southwestern
Ontario
Basins

PEI
2
NB
18

Atlantic
BasinsNS
20

…and has already considerable
experience with CO2 injection and storage
Commercial Enhanced Oil
Recovery (EOR) using CO2
Commercial acid gas injection
from natural gas processing –50+ operations, 1 Mt/yr of CO2
total
Pilot EOR – injecting CO2
Deep Saline Aquifer Storage
pilot projects – early stages;some initial test wells
Pilot Enhanced Coalbed
Methane (ECBM) –completed
CO2 Pipeline
Weyburn-Midale – 2.8 Mt/yr;
also site of IEA CO2 Monitoringand Storage Project
資料537

...but there are numerous challenges
to CCS implementation


Costs



Not yet commercially viable as an integrated
system

Few large-scale demonstrations exist

Lack of infrastructureRegulatory frameworks not yet in placePublic acceptanceTime pressures: need to build new generating
facilities and replace old ones
資料538

CCS Policy in Canada:an Overview
A suite of interdependent initiatives to create theenvironment for implementing CCS

Research andDevelopment(R&D)

National / International
Collaboration

Demonstration
Projects• R&D• Knowledge Sharing• Public Outreach

資料539

Legislation andRegulation

Research and Development in Clean Coal and CCS
Capture

CanmetENERGY (Natural Resources Canada) – CCT and CCS

University of Regina - International Test Centre

Storage

IEA GHG Weyburn-Midale CO2 Monitoring and Storage Project (large
government-industry consortium, incl. RITE; 2000-2011)

North American Carbon Storage Atlas Project (governments of Canada,
U.S. and Mexico)Universities of Calgary, Alberta and SaskatchewanAlberta Innovates -Technology Solutions (Alberta Research Council)



CCS Consortium – Dalhousie University

University of Quebec (INRS)

Legal, Regulatory, Economic and Performance Analyses

University of Regina – International Performance Assessment Centre
for Geological Storage of Carbon Dioxide (IPAC-CO2)

University of Calgary (ISEEE)
資料540

Front-End Engineering and Design(FEED) Studies and Pilot Projects(cost ranges from $33-68 million; mix of public-private funding) ARC Resources – Heartland Area Sequestration Project (HARP) Project to demonstrate feasibility of safe storage of CO2 from industrial
plants in deep saline formations

 Enbridge – Alberta Saline Aquifer Project (ASAP)
 Project to demonstrate technical feasibility of injecting large volumes ofsour CO2 into deep saline formations

 Husky Oil (Heavy Oil CO2 – EOR Project) Assessment of heavy oil CO2-EOR potential in Lloydminster area

 PTRC – Aquistore Project Project involves capturing CO2 from refinery and injection it into nearby
deep saline formation (RITE expected to join a sponsor)

 Capital Power Corp
 Completed. FEED study of 400-MW IGCC coal-based power plant at
Genesee, Alberta

 Wabamun Area CO2 Sequestration Project (WASP) Completed. Comprehensive characterization of large-scale CO2 storage
opportunities and analysisof potential risks
資料541

7 Large (> 1 Mt / yr) Integrated Demonstration Projects
 $7 billion total investments

 >$3 billion in public funding

Coal

Spectra Energy Fort Nelson

Oil / Oil Sands
Gas

BC

Pipeline

TransAlta Pioneer

Swan Hills

Shell Quest

MB

Enhance - Alberta
Carbon Trunk Line

AB

ON

SK
Weyburn-Midale Project
SaskPower Boundary Dam
資料542

TransAlta Project Pioneer
Retrofit of TransAlta Keephills-3 supercriticalcoal-fired power plant (central Alberta)• Base plant (450 MW) under construction; will comeonline in 2012
• Pioneer project comprises retrofit with Alstom’s Chilled
Ammonia post-combustion CO2 capture technology• Will capture 1 million tonnes annually, starting 2015
• CO2 to be used for EOR or to be stored 2,800 metresinto a deep saline formation• Total project cost over CAD $1 billion; federal andprovincial government support: CAD $778.8 million
資料543

SaskPower Boundary Dam Project
Launched in March 2008 by SaskPower•One of the world’s first and largest (140 MW) integrated
CCS demonstration projects at a lignite-fired power plant(located near Estevan, Saskatchewan)•

Re-build of existing unit: boiler and turbine upgrades,
integration of FGD and CO2 capture•

Canadian companies SNC Lavalin – Cansolv (Shellsubsidiary) to provide CO2 capture system (amine-based)•

Will capture 1 Mt of CO2 annually starting 2015•

CO2 to be used for enhanced oil recovery•

Total project cost CAD $1.4 billion; federal support: CAD$240 million
資料544

Swan Hills Synfuels Project
Underground coal gasification (UCG) project inAlberta to provide clean syngas for power plant•

Unique combination of technologies:- Very deep underground coal gasification (1400 m)- Coal gas to be processed in conventional gas plant with CO2
removal to produce clean, low-carbon syngas- Syngas pipelined to 300-MW combined-cycle power plant- Project start-up in 2015•

Will capture 1.4 Mt of CO2 annually•

CO2 to be used for EOR or stored in coal seams depleted
by UCG•

Total project cost CAD $1.5 billion; provincial support:
CAD $285 million
資料545

Weyburn-Midale Project
Commercial CO2-Enhanced Oil Recovery (EOR) Operations
IEA GHG Weyburn-Midale CO2 Monitoring and Storage project
1. Enhanced oil recovery (EOR) operations, injecting CO2 to produce
more oil from depleting oil reservoirs in Saskatchewan:- Cenovus: 6500 t/d or 2.4 Mt/yr (stored to date: 15 Mt)- Apache: 1250 t/d or 0.5 Mt/yr (stored to date: 1.9 Mt)- Commercial operations, no government support

2. IEA GHG Weyburn-Midale Project – world’s largest research
project to examine long-term storage of CO2 in depleting oil fields- Key deliverable: Best Practices Manual (Sep 2011)- Will provide protocols for the development, implementation andoperation of storage projects in oil fields and other formations- Direct public support: $34 million; private sector support: $7 million
資料546

Public Engagement and Knowledge Sharing Public engagement important component of CCS
 Need to acknowledge that the public does not fully understand
CCS, so public engagement in CCS is crucial
 Goal is to gain public confidence in and acceptance of CCS
 Public engagement activities and development of national
strategy underway Launch of national CCS website (www.CCS101.ca) essential
first step in establishing access to CCS information (May 2010)

 Importance of sharing knowledge widely recognized Natural Resources Canada creating knowledge-sharing
framework for large CCS demonstration projects by end 2010
 Knowledge sharing also initiative under Canada - U.S. Clean
Energy Dialogue (CED) Roundtables with industry held in 2008 and 2010
 Initiating collaboration with EU and GCCSI
資料547

Addressing Legal and Regulatory Issues
 Federal and provincial governments working to develop
and refine their legal and regulatory frameworks• Needed to enable deployment of commercial-scale CCS projects• To address outstanding legal and regulatory gaps with shared
responsibilities, e.g. MMV1 requirements

 Provinces have a solid regulatory foundation for CCS• Have jurisdiction over their natural resources, incl. subsurface, andthus have a leading role in regulating CCS projects• Developing CCS regulations based on existing oil & gas regulations,which already adequately cover many CCS activities, incl. injection• Most outstanding CCS legal/regulatory issues relate to pore space
access/ownership and post-injection monitoring/long-term liability• Alberta planning to announce CCS regulatory framework in near
future; Saskatchewan reviewing situation
1 MMV = Measurement, Monitoring and Verification
資料548

Canada Committed to Working with
Domestic and International Partners on CCS•

Federal – Provincial Government CCS Network
•
•
•
•

•

Clean Energy Dialogue (CED) with U.S.
••

Addresses CCS issues of common interest across Canada
Public engagement and outreach
Knowledge sharing
Website: www.CCS101.ca
February 2009 agreement to work collaboratively on clean energy
technology research, development and deployment, including CCS

Participating in / collaborating with:
•
•
•
•
•
•
•
•

Asia Pacific Economic Cooperation (APEC)
Asia Pacific Partnership on Clean Development and Climate (APP)
Carbon Capture, Use and Storage (CCUS) Action Group under the
Clean Energy Ministerial (CEM)
Carbon Sequestration Leadership Forum (CSLF)
European Union
Global CCS Institute (GCCSI)International Energy Agency (IEA)
資料549
U.S. Regional Carbon
Sequestration Partnerships

Summary Energy production is a critical component of the Canadian
economy CCS is of great strategic importance to Canada: deploying
CCS will be key to reach our GHG reduction objectives
 However, there are still many challenges associated with
implementation of CCS
 Both levels of government – federal and provincial – arecollaborating to address these challenges through:• CCS research, development and demonstrations• implementation of CCS policies and regulations• public engagement and outreach• knowledge sharing Over $3.5 billion in public funding allocated to CCS by federal,
Alberta, Saskatchewan and British Columbia governments
 Canada is engaging internationally and among the world
leaders in CCS
資料550

Thank You forYour Attention!
Dr. Frank Mourits
Natural Resources Canada
fmourits@nrcan.gc.ca+1- 613-947-3482

資料551

Other Large-Scale CCS
Demonstration Projects

資料552

Shell Quest Project
Shell Scotford Oil Sands Upgrader (at Fort
Saskatchewan, Alberta)• Joint venture between Shell Canada (60%), Chevron
Canada (20%) and Marathon Oil Sands (20%)• CO2 capture from steam methane units, which producehydrogen to upgrade bitumen to synthetic crude oil• Will capture 1.1 million tonnes annually, starting in 2015
• CO2 to be stored in a deep saline formation• Two injection wells in test phase• Total project cost CAD $1.35 billion; federal and provincial
government support: CAD $865 million
資料553

Spectra Energy Transmission
Fort Nelson CCS Project
CCS at large natural gas processing plant•

Largest shale gas processing facility in region andlargest acid gas (H2S and CO2) operation in North
America•Conventional, amine-based CO2 separation
technology•

Will capture 2.2 Mt of CO2 annually, starting 2015•

CO2 to be stored in a deep saline formation•

Feasibility study received CAD $35 million infederal and provincial support
資料554

Enhance Alberta Carbon Trunk Line
Project to construct 240 kilometre CO2 pipeline•Will employ safe, proven technology to gather, compress
and transport to storage sites up from 1. 6 (Phase 1) up to
14.6 million tonnes of CO2 annually•

Start-up in 2013•

The initial supply of CO2 will come from North West
Upgrading and Agrium (located northeast of Edmonton,
AB)•

Total project cost over CAD $1 billion; federal andprovincial government support: CAD $558.3 million
資料555

Asia-Pacific Economic Cooperation
Clean Fossil Energy Technical and Policy Seminar 2010

Current Status of CCS Projects in Korea

Oct. 28, 2010

Kunwoo Han
Research Institute of Industrial Science & Technology

資料556

Contents
Introduction- Backgrounds/Motivations- Government Actions- Industry, ready to act?

CCS Projects in Korea- Current CCS Projects at a glance- Selected Projects▪ CO2 capture using aqueous ammonia at POSCO/RIST▪ Solvents for CO2 capture at KEPRI and KIER
▪ Dry sorbent for CO2 capture at KEPRI/KIER▪ Promoted K2CO3 solution for CO2 capture at KIER
▪ Offshore CO2 storage: MLTM/KORDI

Summary and Conclusion

資料557

Motivations for CO2 Reduction in Korea
World CO2 Emissions Trend

GHG Emissions in Korea: At a glance
GHG Emissions (MtCO2)

GHG Emissions (tCO2 per capita)[Prediction of GHG Emissions in ROK]ROK ranked among top 10-countries in CO2 –emissions.
Increasing trend in CO2 emissions is predicted.

<Overview of the Republic of Korea’s National Strategy forGreen Growth> by UNEP, 2010
資料558

Government Actions
5-year Green Growth Plan

Reduction of CO2 emissions via CCS should be taken
into consideration for the nation’s green growth plan.

<Overview of the Republic of Korea’s National Strategy forGreen Growth> by UNEP, 2010
資料559

Government Actions
Presidential Committee on Green Growth<National CCS Action Plan> by PCGG, 2010

The most proactive reduction scenario has been chosen.
To achieve Scenario 3, CCS should play a pivotal role.

National CCS Mater Plan released!
資料560<Energy Technology Perspective> by IEA/OECD, 2008

National CCS Master Plan(1/3): What is it?
<National CCS Master Plan>, News Release Translated▪ Overview of the National CCS Master Plan

• Comprehensive action plan for CCS Demonstration in Korea, released on July 13, 2010
• Planned and issued by Presidential Committee on Green Growth and Relevant Ministries• 2.3 Trillion KRW(1.7B USD) in 2010-2019(52% by the Government)▪ Background• Increasing Importance of CCS as a Practical Solution to GHG Emissions• Accelerated Competition on the CCS Market• Need for GHG Reduction and New Growth Engine▪ Vision and Objective• Vision: Growing into the leading countries in CCS technology• Objective: To Secure Plant Commercialization and Technical Competitiveness by 2020
- Verification of Integrated Capture-Transport-Storage System of 1MtCO2/yr- Cost target at $30/tCO2 ($20 for capture, $10 for storage)▪ Benefits/Expectation• CO2 reduction up to 32 MtCO2 by 2030, contributing 10% of total domestic CO2 reduction amount.
• CCS business opens 100 Trillion KRW (cumulative) market by 2030.

資料561

National CCS Master Plan(2/3): Roles and Project Scope
Projects

Ministry in Charge

1. CCS R&D for innovative technology▪ Innovative technology development for CO2 capture, storage▪ Small-scale pilot project (10kt scale)

Ministry of Education, Science & Technology (MEST)▪ CO2 conversion technology

2. CCS commercialization & industrialization▪ CO2 Capture technology Scale-up(10-30MW)

Ministry of Knowledge Economy (MKE)▪ Mid-,Large scale demonstration project

MKE▪ CO2 Transport technology (pipeline, ship) development

Ministry of Land, Transport & Maritime Affairs (MLTM)▪ CO2 Storage capacity evaluation (offshore/onshore)

MLTM/MKE▪ CO2 Storage site selection and management (offshore/onshore)

MLTM/MKE

3. CCS environmental & safety management▪ Legal, regulatory framework (offshore/onshore)

MLTM/Ministry of Environment (ME)▪ Environmental protection technology development (offshore/onshore)

MLTM/ME

4. CCS infrastructure▪ Assist for industrialization (tax, incentive, finance, etc)

ME/Ministry of Strategy & Finance▪ Human resource development▪ Public acceptance

MEST/MKE/MLTM/ME/MOSF▪ International collaboration and network
資料562<Offshore CO2 Storage Project> by MLTM/KORDI(2010)
Courtesy of Dr.Kang, S.G. at KORDI

National CCS Master Plan(3/3): CCS Roadmap in Korea
Year

2010

2011

2012

Phase

Pilot

Scale

10~30 MW
Storage Capacity
Evaluation

2013

2014

2015

2016

2017

Deployment

Demo(20by20)
100~200 MW (1MtCO2 level)

Storage Site Selection(Verification)

Storage Site Selection

Storage Site Preparation

Completion of Saftey
Verification control on
Storage Site

Safety and Environment Risk Assessment
Technologies for Leakage Prevention,
Monitoring, Risk Evaluation

Construction of Env. Control. System

Leak protection & monitoring

Marine environmental management

Post-combustion Pilot

Demo plant
Construction

Pre-combustion/Oxy-fuel Pilot

CO2
injection(Liaison with IGCC?)

1 Mt
Integrated
CCS

demonstratio
n
1MtCO
2

Demo project

Non-Power Sector CCS Pilot
Novel CO2 Capture Pilot

Core R&D for CCS (10kCO2 scale pilot)

Financing

National R&D (Private participation)
Mainly by Government

Full scale

Site Control & Investigation of New
Storage Potential Site

Confirmation ofStorage Site

Foundation for 1MtCO2/yr Storage

Actions<Offshore CO2 Storage Project> by MLTM/KORDI(2010)
Courtesy of Dr.Kang, S.G. at KORDI

SPC (Industry Investment+Government Support)
Mainly by Private Sector
資料563

Deployment(Domestic
Storage &Export)Deploymentof CCSof 3Mt-scaleIndustrial Action – Foundation of “Korea CCS Association”
 Major Hallmarks<Overview of the Republic of Korea’s National Strategy for Green Growth> by UNEP, 2010

 Initiated by Prof.Han at SNU in Aug. 2010.
 Pre-meetings & Public presentations for membership have hosted in Sep.
 Official foundation ceremony of Korea CCS Association will be hosted in Oct., 2010

 Objectives
 Commercialization/Industrialization of CCS
 Planning and Evaluation of CCS R&D for Verification, Commercialization and Industrialization
 Expansion of CCS deployment and Help for Technology Export

 Roles Investigation/Analysis/Distribution of Global CCS Commercialization Activities
 Establishment of CCS Verification, Commercialization and Industrialization
 Establishment of Ideas of Policy, Regulation for Deployment, Expansion and Technology Export
 Setup of guidelines/standards for evaluation and permission of CCS commercialization
 Preparation of systems for investment promotion and finances, insurances for the private funds
 PR Activities for the public acceptance: Seminar, Champaign, etc.
 Promotion for international collaboration, human resources development, etc.

 Member Companies (As of Sep.)
 (Chair) KEPCO, 5 Power Companies, Korea National Oil Corporation, POSCO E&C, KC Cottrell, Doosan Heavy
Industries & Construction, etc.
資料564

Status of CCS Projects/Technologies in ROK
Highlights!

International Timeline

Some of the core developments have been made.
Storage and system integration project has hardly been conducted.

<National CCS Master Plan>,
8th Report by Green Growth Committee (2010.7.13)

Two Large-Scale Demonstration Projects Proposed.

<Carbon Capture and Storage: Progress and Next Steps> by IEA/CSLF Report to the Muskoka 2010 G8 Summit
資料565

CDRS in Action
The first national (major) project for CCS- 3-phase, 10-yr(2002-2012), $140 USD- primary focus on CO2 capture technology development

Major R&D Technology

Follow-up national project is under consideration.
資料566

Overview

Selected CCS Projects in Korea
 CO2 Capture SEWGS (Sorption Enhanced Water-Gas Shift) Process: KEPRI, KIER
 Absorption using Aqueous Ammonia at POSCO/RIST, KIER
 Amine-based CO2 Capture: KEPRI, etc.
 Solvent for CO2 Capture at KIER
 CO2 absorption using promoted K2CO3 solution at KIER
 Dry sorbents for CO2 capture (Fluidized bed adsorption): KEPRI/KIER
 Pressure swing adsorption: KIER
 Membranes for CO2 capture: Hanyang Univ., KIER, etc.

 Oxy-fuel Combustions
 Oxy-fuel combustion - CO2 recycling: KIER
 Chemical looping combustion: KIER

 CO2 Storage

 Offshore CO2 geological storage: KORDI, KIGAM, KNOC, etc.
 CO2 storage under the ground: SNU, etc.

 CO2 Utilization/Conversion/Fixation

 CO2 conversion to polymers: Ajou Univ., SK Energy, etc.
 CO2 conversion into chemicals: Sogang Univ., RIST, POSTECH, KIGAM, etc.
資料567

CO2 Capture using AA (1/2): Iron and Steelmaking at a glance
Key reaction in “Iron and Steelmaking”

Fe2O3, Fe3O4 + Carbon → Fe + CO2· Majority of CO2 (~90%) emissions comes from “iron-making” process· “… ‘CO2’ will be the most challenging issue which POSCO will facein the near future…”· POSCO will reduce CO2 emissions 9% based on BAU in 2020.

資料568

CO2 Capture using AA (2/2): Project Overview■ Technology Overview• Development of aqueous ammonia based CO2 capture technology- BFG containing 20~25% of CO2 being used as a feed gas- Low concentration(< 10 wt%) aqueous ammonia as a solvent- Waste heat will be utilized as a regeneration energy• Target : CO2 recovery ratio ≥ 90%, Purity of product CO2 ≥ 95%
CO2 capture cost lower than $20/t-CO2 via waste heat recovery■ R&D History/Plan• 2006-2007, Lab-scale basic research• 2008, Design, construction and test runs of 1st stage pilot plant (50 Nm3-BFG/hr; 0.5t-CO2/d)• 2009-2010, Field tests, operation, and process optimization of the pilot plant• 2009-2014, Design, construction and operation of 2nd stage pilot plant(1000 Nm3-BFG/hr,10 t-CO2/d)
Government-funded project(5 Years, $ 27M, Ministry of Knowledge Economy)■ Results of Field Tests

Product CO2

Processed BFG(Washing/Waste) Water

50

Gas Flow Rate(Nm3/hr)• Operation condition- BFG inlet at ~ 50 Nm3/hr(CO2 conc. ~23 vol%)- CO2 removal ~ 90%• Product gas(CO2 recovery in stripper)- Product gas (CO2) :~12 Nm3/hr (> 20kg-CO2/hr)- CO2 gas purity: > 95%(usually 97~98 vol%)60

Washingwater

Washingwater

40

Blowdown(BF/Ammonia)Gas

Drum

Aqueous ammonia(Low/High P) Steam

30

20

10
BFG inlet

0
0

200

400

600

800

1000

1200

Reboiler
Rich Solution

Lean solution
Reboiler

Time(min)[Fig] Flow rates in absorber and stripper
資料569

Absorber

Regenerator

Concentrator

Waste
water

Solvents for CO2 Capture at KEPRI
10MW

KoSol-series development
at Korea Electric Power Corporation

About 30% performance improvement compared to MEA

Ready for CO2 capture pilot plant operation

Trial runs are currently being performedat Boryoung Power Station.

資料570<CO2 Capture Technology at KEPCO> by Ryu, 2009

Solvents for CO2 Capture at KIER
KIER-C3 for CO2 capture• Absorption characteristics have been measured.
• Mixture solvents are being developed.

Field tests for CO2 capture pilot plant are being done.
• Apply to actual conditions (coal fired facility, small P/P)
- Capacity : Flue gas flow rate ; 1,000 Nm3/hr(CO2 Recovery rate ; 5.0 ton-CO2/day)- Start up : Jul. 2009
- Location : Daejeon, Korea (in KIER)

Design for commercialization

Courtesy of Min, 2010
資料571

Promoted K2CO3 solution for CO2 capture
Courtesy of Dr.Yoon, Yeoil at KIER

Disadvantages of MEA Process

Characteristics and Applicability
Promoted K2CO3 process
1. Low Regeneration E: 2.3~2.5 GJ/tCO2
2. Little make-up: Low vaporization loss, few side reactions
Little effect by O2, SO2 and impurities
3. Simple process: consists of absorber and stripper simply
4. Can treat high CO2 concentration gas streams

Solvent
Concentration

Solvent
Loss

Solvent
Make upRegeneration
Heat
Phase 3 (’08. 4 -’12. 3)
2006.4Lab scale-▪ Higher CO2 absorption rate and capacity→ An alternative to the MEA process and various industries
with high concentration CO2▪ Lower reaction heat and lower degree of the side reactions →Absorbent for post-combustion (low operation cost)
Scale up (’15)

2010. 2

Bench process

2012

Pilot

Commercialization

Process

Absorber Temperature
80

1
75

2

T (¡É)

70
65

3

60

4

55

5
50
L/G = 1.5
L/G = 2.5
L/G = 3.5
L/G = 4.5

45

6

40
1

2

3

4

5

6

Absorber Number• 0.001 Nm3/h• 10 Nm3/h• 1000~2000 Nm3/h
資料572• 10~30 MW (PC power)

Dry Sorbent for CO2 Capture

Dry Sorbent Technologies at KEPRI

The Korea Electric Power Times, Mar. 9, 2010

資料573

<CO2 Capture Technology at KEPCO> by Ryu, C.K., 2009

CO2 Storage Under the Seabed
Conceptual CCS Application in Korea
Future Plan for CCS by MLTM
Power plant

Power plant

Steel-making
plant

Schedule

1.Storage site section in offshore
sediments’10 -’15

2.Implementation of demo-scale
CCS project and the deploymentof full scale projects in Korea’16 –4.Legal and management systemfor offshore CCS’10 –5. R&D for technology for CO2
storage in offshore sediment& its
environmental management(including site selection)’05 - ’15

Ulleung basin(near gas reservoir) 3. CO2 Transportation for CCS in ’16 –Korea

Power plant
Steel-making
plant
Aquifer(Gunsan Basin)

Project Items

Aquifer(Jeju Basin)

CO2 Transport
Carrying-vessel
Pipeline

資料574<Offshore CO2 Storage Project> by MLTM/KORRI

Summary and Conclusions
Proactive Government Actions:- Ambitious target at 30% reduction of CO2 emissions was chosen.
- “National CCS Master Plan” released recently.

Industry Activities- Korea CCS Association to be established.
- Active R&D in power-generation and steel industry.

Selected CCS Projects Presented- CO2 capture using aqueous ammonia from BFG at POSCO/RIST- Solvents for CO2 capture at KEPRI and KIER
- Dry sorbent for CO2 capture at KEPRI/KIER- Promoted K2CO3 solution for CO2 capture at KIER
- Offshore CO2 storage : MLTM/KORDI

CCS in Korea- Some research accomplishments have been made, specifically on CO2 capture technology.
- Plan to actively work on CCS verification/demonstration/deployment.
- Relatively slow progress in CCS demonstration.
- Geology-specific CO2 storage strategy under development.
資料575

Thank You!

Kunwoo Han, Ph.D.
Senior Research Engineer/CO2 Project
Research Institute of Industrial Science & Technology
E-mail: khan@rist.re.kr
Phone: +82-54-279-6291

資料576

(12) セッション 4B(ii)

資料577

Toshiba’s Activity in
Post Combustion
CO2 Capture Technology
October 28, 2010
Kiyoshi Miyaike
Power Systems Company
Toshiba Corporation– © TOSHIBA CORPORATION 2010, All rights reserved.

資料578

1 / 17

Toshiba’s Clean Coal Technologies

Impact on Environmental
Improvement

Large

Post Combustion CO2 CaptureTechnology for CCS

New Plant

Existing Aged Plant

Improvement ofHeat Cycle Efficiency

Up-rating & Efficiency
Improvement by
Steam Turbine Retrofit

by USC ＆ A-USC

Efficiency Improvement of Core Components- Steam Turbine，Generator, Heater, etc -Small– © TOSHIBA CORPORATION 2010, All rights reserved.

資料579

2 / 17

Mikawa PCC* Pilot Plant*PCC : Post Combustion Capture

Location:

Plot Plan:
PCC Pilot Plant

Tokyo
ESP

Stack

FGD

Boiler
Turbine Unit

47.5MW Coal Fired Power Plant
Sigma Power Ariake Co., Ltd.
Mikawa Power Plant
Omuta City, Fukuoka, Japan– © TOSHIBA CORPORATION 2010, All rights reserved.

資料580

3 / 17

PCC Pilot Plant - Outline and Objectives Plant Outline
9Test Commenced : September 29, 20099Technology: Amine-based Chemical
Absorption Method

9Capture Capacity : 10 ton-CO2 / day
9Flue Gas Flow

: 2100 Nm3 / hour

Main Objectives
9Testing of system using actual flue gas ofa live thermal power plant
9Verification of performance, operability,
maintainability, etc., in view of scaled up
plant design.

– © TOSHIBA CORPORATION 2010, All rights reserved.

資料581

4 / 17

PCC Pilot Plant - System Configuration 47.5MW Coal Fired Plant
BoilerSteam Turbine ＆Generator

Stack
FGD
EP
Condenser
Steam
Captured CO2
Flue Gas after
CO2 Separation

Condenser
Condenser
CoolerStripperBoiler FlueGas

PCC Pilot Plant

Heat
Exchanger
Absorber
Pump

BlowerAdditional
FGD

Pump
Solvent(Rich)

Reboiler
Solvent(Lean)– © TOSHIBA CORPORATION 2010, All rights reserved.

資料582

5 / 17

PCC Pilot Plant - Schedule and Tests 9 Process Evaluation : Ensure stable operation and good measurement accuracy
9 Performance Tests : Seek higher CO2 capture efficiency
9 Continuous Operation Test ： Ensure reliability of system operation
9 Load Change Tests : Evaluate response at transient operations
9 Absorbent Life Test : Evaluate absorbent degradation by live flue gas

Cumulative Operating Hours

Total Operating Hours : 3901 Hours (as of July 15, 2010)
Test Period-3
Continuous Operation Test／Load Change Tests

Test Period-1

Test Period-2

Process Evaluation

Performance Tests(2328h)Absorbent Life Test
(3002h)Date– © TOSHIBA CORPORATION 2010, All rights reserved.

資料583

6 / 17

Test Result (1) - CO2 Capture Efficiency 9CO2 Regeneration Energy : 3.2～3.3GJ/t-CO2 at 90% of CO2 capture ratio
Energy consumption will be reduced by 15~20% practically by further system
improvement.
9Purity of captured CO2 : >99%

12

95
90

Captured CO2 [t/D]

CO2 Capture Ratio [%]

100

90%

85
80
75
70
2.8

2.9

3.0

3.1

3.2

3.3

3.4

3.5

3.6

3.7

11
10 t/D
10
9
8
2.8

3.8

CO2 Regeneration Energy [GJ/t-CO2]

2.9

3.0

3.1

3.2

3.3

3.4

3.5

3.6

3.7

3.8

CO2 Regeneration Energy [GJ/t-CO2]– © TOSHIBA CORPORATION 2010, All rights reserved.

資料584

7 / 17

Test Result (2) - Absorbent Life Test 9 Very small degradation in absorbent performance was observed after

100

20

90

18

80

16

CO2 Capture Rate

70

14

60

12

50

10
Amount of Captured CO2

40

8

30

6

20

4

10

2

0

0
3000

0

500

1000

1500

2000

2500

Amount of Captured CO2 [t/D]

CO2 Capture Rate［%］about 3000 hours operation.
9 Increase rate of degradation products such as organic acids and Amine
compounds were evaluated.

Points were plotted for fixed test
conditions-Flue gas flow rate and temp.
-Absorbent flow rate and temp.
-Heat input of reboiler

Cumulative Operating Time [hr]Result of Absorbent Life Test
– © TOSHIBA CORPORATION 2010, All rights reserved.

資料585

8 / 17

Test Result (3) - Dynamic Response Test -AbsorberBoundary
Condition
Heat Exchanger

StripperCondenser

Reboiler

CO2 Concentration at Absorber outlet（％）

9Dynamic Simulation Model was established for ensuring appropriate
plant control.
（1000～4600sec)
100%
75%
100%
2.8
2.6
2.4
2.2
2.0
1.8
1.6
1.4
1.2
1.0

Simulaton

Measured
0

2000

4000

6000

8000 10000

Time (Sec）
Example of Dynamic Response Test
（Sudden Change in Steam Flow）

Simulation Block Diagram– © TOSHIBA CORPORATION 2010, All rights reserved.

資料586

9 / 17

Test Result (4) - Material Corrosion Test 9Neither corrosion nor thinning on all coupons were observed at Absorber.
9Corrosion and thinning on Carbon Steel were observed, while no damages
were observed on SUS at Stripper.
Buffer Tank

Flue Gas
to Stack

CO2
Condenser& Separator

Pump
Lean
Solvent
Rich
Solvent

StripperFlue Gas
from FGD

AbsorberCooler

150mm

Pump

Steam

Heat
Exchanger

Reboiler
Drain

Pump

Pump

SS400

不锈钢 SUS316L

SUS304
SUS316

不锈钢 SUS304
Total Operation
Hours : 3901h

SUS316L– © TOSHIBA CORPORATION 2010, All rights reserved.

資料587

10 / 17

CO2 Capture Energy Consumption (GJ/t-CO2)

Improvement of CO2 Capture Energy Consumption

5
Sensible heat
Latent heat
Reaction heat

4

Energy Reduction
Toward 2.0 GJ/t-CO2

3
2
1
0

TS-1
TS1

TS-1
TS1改

TS-X
TSX

Current
Process
Current

Improved
Process

Improved
Process
Target– © TOSHIBA CORPORATION 2010, All rights reserved.

資料588

11 / 17

Percentage ofof ElectricPower Against
Against Generator
Generator Output
Percentage
Percentage
ofElectricPowerPower
Consumption
and Output
OutputEvaluation of Plant Efficiency with CCS

100
100

Power
Power Block
Block Aux.
Aux. Power
Power
CO2
CaptureAux.
CO2 Capture Aux. Power
Power

90
90
80
80

88
55
23
23

Plant
Plant NetNet Output
OutputCO2
Compressor
CO2 Compressor Power
Power

88
55

CO2
CO2 Capture
Capture Energy
Energy

88
55

17
17

12
12

88
55
10
10

70
70

72
72

70
70
60
60
50
50
40
40
30
30

59
59

65
65

20
20
10
10
00

Reduction of
Plant Efficiency

55

55

55

55

11
MEA

22
TS1
Current Process
D13.8pt33
TS-1＋Process
Improvement
D11.5pt

44
TS-X
TargetD10.3pt

D16.3pt– © TOSHIBA CORPORATION 2010, All rights reserved.

資料589

12 / 17

CCS Technology Deployment
Subjects
9 Improvement of CO2 capture energy consumption including new solvent
development and integration with power plant system
9 Establishment of large CO2 capture system design
9 Planning and participation in large CCS/CCU demonstration projects
9 Proposal for CCS readiness plants
9 Integration with high efficiency A-USC technology
Timeline
CCS
Deployment

2000

2010

R&D

CCS
Plant
Engineering
Plant
Efficiency
Improvement

2020

Pilot Full Scale Commercial
Plant Demo Plant Plant Verification

2030
Commercially
Proven Plant

CCS Readiness
Plant Engineering
Existing
SC / USC
Technology

A-USC
A-USC＋CCS(600/700C)(700/750℃)
Validation
Validation– © TOSHIBA CORPORATION 2010, All rights reserved.

資料590

13 / 17

Modular Plant Design
Feed Gas
Blower

Cooling
Water Piping

Feed Gas
Cooler

Absorber
Pumps

Lean Solvent
CoolerCross
Heat Exchanger

Lean Solvent
Buffer Tank

Condenser

Pumps

Reflux
Separator

StripperReboiler Drain Tank

– © TOSHIBA CORPORATION 2010, All rights reserved.

資料591

14 / 17

Integrated CCS Plant Configuration
9Carbon Capture needs to match Power Plant
Requirements in both performance and operability
Boiler

BUF

SCR
GGH

ESP

GGH
IDF

FGD

Stack

GAH

Feed Gas Blower
CO2 Compressor
Liquefied
CO2
Condenser

Extraction Steam System

Buffer Tank

G

StripperLean Solvent
Absorber
Pump

Steam Turbine Generator

Reboiler

Condenser

CEP

LP
Heaters

Deae
BFP

Cross Heat
Exchanger

HP
Heaters

Lean Solvent
Booster Pump

Drain Recovery System

Rich Solvent
Pump– © TOSHIBA CORPORATION 2010, All rights reserved.

資料592

15 / 17

Summary
9

Toshiba Corporation has embarked on commercialization of CO2
Capture Technology, starting with the Pilot Plant work at Mikawa.

9

Toshiba has already made preparation for execution of large
scale CCS projects on actual power plants.

– © TOSHIBA CORPORATION 2010, All rights reserved.

資料593

16 / 17– © TOSHIBA CORPORATION 2010, All rights reserved.

資料594

17 / 17

Current Status of CCS Projectin Chinese Taipei
Shoung Ouyang
Green Energy and Environment Laboratories
Industrial Technology Research Institute2010/10/28
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料595

Contents

 Global carbon reduction and CCS
 Energy structure and CO2 emission in Taiwan
 Sustainable energy policy and challenges ahead
 CCS research activities
 Closing remarks

Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料596

1

Global Carbon Reduction and CCS

Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料597

2

Global Carbon Reduction and CCS
 BLUE Map scenario in IEA Energy Technology Perspective (2010):
Global CO2 emissions reduction of 43 billion tons by 2050

Ref : International Energy Agency, Energy Technology Perspective, 2010.
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料598

3

CCS Technology Overview
 PERFORMANCE CO2 Capture > 90%, power plant efficiency reduced 8~12 %.
 COST Cost : capture US$ 20~80/t; transport US$ 1~10/t per 100 km;
storage and monitoring US$ 2~5/t.
 Projected CCS cost by 2030 is around US$ 25/tCO2, with impact onelectricity cost of US$ 0.01~0.02/kWh.
 STATUS
 Several dozens of oil fields use CO2 for EOR (~40 MtCO2/year).
 CCS is already being demonstrated in some small-scale pilot plants.
Large-scale integrated projects are underway or planned.
 BARRIERS Cost of large-scale demonstration projects; operational cost;demonstration of safe storage.
 Needs for regulatory framework; governmental policies andincentives for emission reduction; public acceptance.
Ref.: Energy Technology Essentials, IEA 2006
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料599

4

Key Areas of CCS R&D
CO2 Capture Approaches: Aqueous Chemical absorption (Amine-based) CO2 Hydrate H2/CO2 Membranes (H2 permeate, ceramic &polymer N2/CO2 Membranes (Enzymatic,
membrane/amine hybrid) Solid Sorbents (amine-enriched, CaO, nanoporous, metal organic frameworks)
 Ionic Liquids
 Microbes, algae Advanced Fuel
Transformation
Approaches(produce high CO2
concentration):
 Gasification
 Oxy-fuelcombustion
 Chemical
LoopingCO2 Storage Approaches: Geo-Sequestration (depleted oil/gas reservoirs,

unmined coal seams, and deep saline formations) Mineralization
 Ocean sequestration
 Measurement, Monitoring & Verification (MM&V)
Ref.:Carbon Sequesration Technology Roadmap and Program Plan-2006, NETL/DOE, June, 2006
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料600

5

Energy structure andCO2 emission in Taiwan

Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料601

6

Structural Comparison of Electricity Generation
Electricity Emission Coefficient of Taiwan in 2009: 0.623 kgCO2/kWh(1990: 0.48 kgCO2/kWh)Fossil fuel: 90.9%

Nuclear:8.7%

Gas: 8.6%(tCO2e/kloe)
Coal: 3.8483
Oil:

Coal:
30.5%

Oil: 51.8%

Hydro:
0.4%

Nuclear:
18.1%

Wind:
0.16%
IPP:
17.35%

Hydro:
3.01%

CoGen:
17.29%

Coal:28%

Fossil fuel: 78.74%

2.8862
Gas:13.43

LNG: 1.9841
Japan 2005: 0.429 kgCO2/kWh
Biomass:
1.1%

Waste:0.6%

Gas:21%

Fossil fuel: 62.3%
Oil:13.2%

Ref: 民國98年能源統計手冊，能源局(2010)；台灣節
能減碳趨勢下的產業結構調整，工業局(2008)

Copyright 2010 ITRI 工研院

Nuclear:
27.6%

Coal:
28.1%

Hydro:
7.8%

Geother
mal:0.3%

Oil:2.67%

Korea 2005: 0.418 kgCO2/kWh

Oil:
6.7%

Gas:16%
Nuclear:
37.7%
Coal:
38.2%

Wind:0.2%

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料602

Hydro:1.3%
Other:0.1%

Fossil fuel: 60.9%
7

Taiwan CO2 Emission by Sectors (2009)••

Excluding Emission from Electricity Consumption: Energy(158Mt, 65.9%),
Industrials(38Mt, 15.9%),Transportation(33Mt,14.0%), Residential(5Mt, 2.1%),
Services(4Mt, 1.7%), Agricuture(1Mt, 0.4%)
Including Emission from Electricity Consumption: Energy(25Mt, 10.4%),
Industrials(111Mt, 46.1%), Transportation(34Mt, 14.3%), Residential(33Mt, 13.9%),
Services(34Mt, 14.2%), Agricuture(3Mt, 1.1%)

Ref: Bureau of Energy, MOEA, Taiwan (2010)
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料603

8

Major CO2 Emitters in Taiwan
 CO2 emission of fossil

fuels-fired power plants(156 Mtons, 58.7% of total
emission in 2006)
 TPC (60.76%)
 IPP (20.67%)
 Co-Gen (18.57%)

Large Stationary Emission Source in Taiwan
Sources87.1 MtCO2/yr CO2 emission from industrial

sector (138 Mtons) among which
Petrochemical and Iron
and Steel Industries: 53
Mtons, ~ 38.5%)

Copyright 2010 ITRI 工研院

Linkou3.96 MtCO 2/yr

Xiehe
7.22 MtCO 2/yr
Shenao2.64 MtCO 2/yr

Taichung
36.8 MtCO 2/yr

Heping
7.7 MtCO 2/yr

Mailiao
32 MtCO2/yr
Hsingda18.3 MtCO 2/yr
Dalin
6.39 MtCO 2/yr
Linhai20.8 MtCO2/yr

total emission from thermal power plant in2006 was 156 Mtons, accounted to 58.7% ofnation-wide emission

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料604

9

Potential Target for CO2 Reduction by CCS
 Projections of Taiwan’s CO2  CCS is predicted to contributeemission in 2025 for the
19-20 % of global CO2
BAU scenario: 522 to 577
emission reductionsb by 2050.
Mtons (Ave. 550 Mtons)a.
 If the CO2 emission in 2025
is to be reduced to 2000
level (215 Mtons): theamount of CO2 reduction in
2025 is 335 Mtons.

Ref：a. Carbon Economy Monthly, No. 1, September 2006, pp. 45 ~ 49
b. Energy Technology Perspective, 2010, International Energy Agency
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料605

10

Sustainable energy policy andChallenges ahead

Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料606

11

Sustainable Energy Policy Guidelines
Clean
CleanEnergy
Energy Reform of Energy Structure and Efficiency Elevation
1. expediting development and effective utilization of zero-carbon
renewable energies (8% of electricity generation by 2025)
2. increasing the use of low-carbon LNG (25% of electricity generation by2025
3. enhancing energy diversity, nuclear remains as alternative for zerocarbon energy source
4. expediting phase-out of old power plants and installation of new ones
with best optimized generation efficiency
5. introducing carbon capture and storage technology through international
cooperation and collaboration, to lower carbon emission of electricity
generation systems
6. normalizing consumers’energy price, to reflect the inner cost in shortterm, and to gradually incorporate the outer cost in medium or long term
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料607

12

Our Challenges
 Status of energy supply and CO2 emission
 99% of energy supply rely on importation
 emit approximately 260 Mt CO2 in 2005, ~1% of global CO2

emission, ranked 22nd globally Sustainable Energy and 3E Policies
 improve energy efficiency
 provide stable energy supply
 balance energy/environment/economy
 develop clean energy

EnergyEnviron.

 Reduction of CO2 emission
 reduce CO2 emissions of 2016-2020 to the 2005 level further reduce the emission to the 2000 level by 2025
 increase the percentage of low carbon energy for electricity
generation above 55% by 2025

EconomyRef.:1.IEA/OECD,CO2 Emissions from fuel Combustion 1971~2005, 2006 Edition
2.Energy Balances in Taiwan ,MOEA BOE,2006
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料608

13

CO2 Emission from Electric Power Generation(2008-2018)(Kg CO2/kWh)(CO2 Mt)

Note: Power generation sector include TPC, IPP, and Co-generation。
Copyright 2010 ITRI 工研院

Ref: Bureau of Energy, MOEA, Taiwan 2009

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
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14

Thoughts for CCS Development in Taiwan
 General Considerations
 Carbon capture is focused on the large and stationary point emitters ofCO2, that is post-combustion capture.
 Carbon storage is better concentrated on sequestration in deep saline
aquifers.
 Urgent needs for policy and regulatory framework to ensure timely
advancement of CCS.
 Teamwork and technology integration are essential to the deploymentof CCS technology.

 Technology Development
 CO2 capture: technology and commercial-scale demo & verification

before 2025 with calcium looping process and solid sorbents
 CO2 storage: site characterization technology, assessment of storage
potential, simulation and prediction of CO2 plume migration,
monitoring/verification/accounting techniques.

Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料610

15

CCS Research Activities

Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料611

16

Estimation of Geologic Storage Potential - ITRI
Caprock

桃園

Estimated Capacities:
1.Oil & Gas Land
Reservoirs: 2,800 Mtons
2.Offshore Saline Aquifers:
9,000~68,000 Mtons(NW: 2,300~20,000
Mtons)

N

N: 66~219億噸

雲林S1
義竹斷層 S2B斷層

S1: 19~68億噸

S2: 10~34億噸
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料612

17

Post-combustion Capture - Calcium Looping - ITRI
 Complete the 48-hr continuous test with the bench scale experimental
system, with capture efficiency greater than 98% (CO2 conc.: 11~16%)
 Plot the scale-up design of oxy-fuel and rotary kiln calciner Complete the conceptual design of CaCO3/CaO looping pilot plant

CO2 capture capacity is 1 ton/hr
Fluidized bed for carbonation
Oxy-fired rotary kiln for calcination
Target of capture cost < US$ 40/t CO2

120
100

捕
獲 80
效
率 60
(
% 40
)

Burner

20
0
0

500

1000

1500

2000

2500

3000

3500

時間(分)

Test result of CO2 capture efficiency
Flow chart of 1MW pilot plant
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料613

18

Meso-porous Silica-based Particles (MSP) - ITRI The first pilot-scale preparation of MSPs with aerosol

process instead of sol-gel process－Surface area＞1000 m2/g
－Uniform pore size distribution(2.38~2.80 nm)－Production scale-up being reliable and easy.

 Preparation capacity has increased from 1g/8hr to 100

SEM Analysis of MSPs

g/hr, it will be scaled up to 1000 g/hr in 2011
 MSPs modified with tetraethylenepentamine (TEPA)and ethylene-diamine (EDA) for enhancing adsorption
capacity CO2 adsorption capacity－2.0~4.67 mmole/g (modified with TEPA at water contents of
0~7% and CO2 conc. of 15% )－recovery ratio >99% (after 20 times of thermal recycle).
NETL

Nanking Univ.

TEM Analysis of MSPs

ITRI
(2010)

ITRI(2012 Target)

Adsorption
Adsorption
Adsorption
Adsorption
Capacity (mmol/g) Capacity (mmol/g) Capacity (mmol/g )Capacity (mmol/g )3.02
3.7
2~4.67 (powder) ＞4 (Pelletizing)
Surface modification by EDA
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料614

19

MOEA CCS R&D Alliance
CO2 CaptureTechnology
Development

Injection/Storage

Site Assessment

CCS
R&D
Alliance

Technology
Demonstration

CO2 Capture
Oil/Gas Structures
Saline Aquifers
Intl. Cooperation

Others

BOE

Monitoring
Simulations

MOEA

Capture Technology

Laws/Regulations

CO2 Capture DEMO BOE/TPC/CSC
Site Assessment and BOE/CPC/
Storage Capacity CGC/TPC
Storage DEMO in
Geologic Structures CPC
Storage DEMO in
Saline Aquifers

TPC/CPC

Storage Technology BOE/TPC/CPC

Public Outreach Technology R&D (capture, storage, monitoring, simulation)
 International collaboration, regulation,
 Characterization and evaluation of potential sites
and public outreach Technology Demo (Capture, Dome-shaped structure, and deep saline  CCS Industry Promotion
aquifer)
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料615

20

Proposed Roadmap for MOEA-CCS Alliance
Strategy 1: Focus on large CO2 emitters First priority: Fossil fuels-fired power plants(amounted to 58.7% of total CO2 emission in 2006)

Commercial Operationof CCS Starts at 2025

 Secondary priority: Petroleum & Steel Industries(amounted to 20% of total CO2 emission in 2006)

Strategy 2: Stepwise approach2025
2020-21
Full-Scale Commercial Capture Plant DesignLarge-scale CO2 Injection Deployment

2016-18
 10~30 MW post-combustion CO2 capture

demo plant Medium-scale CGS pilot test site (10~100 kt
CO2/year)

2012-14
 1 ~ 3 MW post-combustion CO2 capture pilot plant Small-scale CGS pilot test site (1~10 kt CO2/year)
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料616

21

CPC Corporation
 Current Research Site Selection / Potential / Trapping Mechanism
 Site Selection Procedure Capacity Assessment of Depleted Gas Field Capacity Assessment of Saline Aquifer (TCS)

Survey of trap structuresand reservoir assessment

 Planning on Pilot Injection Site

 Planned work Reservoir Characterization
 Geophysical Monitoring Technique Numerical Simulation
 Soil Gas Monitoring Impact to Current Production Wells

Drilling (1 injection well, 2monitoring wells)

Tests of injection and sealing

Monitoring Collaboration


EPA / BOE / NSC-NEP / TPC / CSC
 Other Ongoing International Projects

Analysis of risk, benefit, and public
outreach
Ref: Wu R.Z., CPC, 2010

Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料617

22

Taiwan Power Company
 Current Research CO2 Utilization
 Microalgal CO2 fixation byphotobioreactor
 Derivatives Application of Microalgal

 Advanced CO2 Capture Technology
 low-cost post-combustion capture (study)
 Calcium Looping (with BOE and ITRI) Novel CO2 absorbent development

 Off-shore Geological CO2 Storage(2008-2010)
 Geological investigation and site

selection of sub-seabed geologicalformation for CO2 storage
 Estimation of CO2 storage capacity foroff-shore geological CO2 storage
 Measures and remedies for off-shore
geological CO2 storage
Ref: Lan C.R., TPC, 2010
Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料618

23

China Steel Corporation
 Research Interests

CO2 capture CO2 sequestration

NCKU Burner(CO2 up to 28%, Target 35%)

CO2
CapturePilot Plant

Burner bio-fixiation

Fuel mineral sequestration (slag)

O2 or AirCO2
H2O

 CO2-utilization

Stack

100kg/day Technology Development
flue gas recirculation(CO2 / H2O)

CO2 Breakthrough Program Oxy-combustion (with flue gas recirculation)
 CO2 Capture

Blast Furnace #3
CO2 Capture Pilot Plant

In cooperation with NSC-NEP NTHU, NTU, NTUST (Capture and Utilization)
 NCKU, NCTU (Oil from Algae  Biodiesel)Annual Budget: NTD$ 20M

 Future: TGR-BF
Top Gas Recycling Blast Furnace technology including CCS

CO2 Breakthrough Programme from 2009
Copyright 2010 ITRI 工研院

Algae (On-site)

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料619

Ref: Ou Z.Z., CSC, 201024

Closing Remarks
 CCS is a MUST for sustaining the continued use of fossil fuels.
 CCS is envisioned to play a more significant role for Taiwan’s situation.

Speed-up of the RD&D is necessary.
 Urgent needs for policy and regulatory framework to expedite the CCS

development and deployment.
 Pilot-scale demonstrations are essential to the CCS technology

development and public outreach.
A Vision for Future CCS Implementation in Taiwan

Industrial Gasification Plant

Low Emission
Power Plant
Saline Aquifer
Geological Sequestration

Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料620

25

Thank You
forYour Attention

Copyright 2010 ITRI 工研院

APEC Clean Fossil Energy Technical and Policy Seminar 2010, Fukuoka, Japan, 27-29 October
資料621

26

Assessment of the capture and storage
potential of CO2 co-produced with natural
gas in South-East Asia
APEC project EWG 06/2008A

CO2CRC Technologies Pty Ltd
Cooperative Research Centre forGreenhouse Gas Technologies (CO2CRC)
The University of New South WalesAPEC – New Developments in Clean Coaland CO2 Reduction Technologies

資料622

Contributors• CO2CRC
Peter Neal
Wanwan Hou
Yildiray Cinar
Olga Bukhteeva
Geoff McKee (advisor)
Guy Allinson• Australian Petroleum Production & Exploration
Association (APPEA)
Damian Dwyer
資料623

Acknowledgements
Discussions with •
•
•
•
•
•
•
•
•
•
•
•
•

Indonesian Ministry of Energy & Mineral Resources, Lemigas.
Indonesian Executive Agency For Upstream Oil and Gas Activities (BPMigas).
Chevron Thailand Exploration and Production Ltd.
Thailand's Ministry of Energy.
Thailand's Department of Mineral Fuels, Ministry of Energy
Oil Search Ltd (PNG)
PetroVietnam Exploration Production Corporation.
Petronas Carigali Sdn Bhd.
Petronas.
PT Shell Indonesia.
Total E&P Indonesie.
BP Indonesia - BP Berau Ltd.
Statoil Indonesia.
資料624

Acknowledgements
Steering committee• Frank Mourits
APEC Expert Group on Clean Fossil Energy.
• Scott Smouse
Chair of the APEC Expert Group on Clean Fossil Energy• Damian Dwyer
Australian Petroleum Production & Exploration Association – APPEA• David Hilditch
CO2CRC Technologies Pty Ltd (CO2TECH),

International Energy Agency• Brett Jacobs.

資料625

Contents
Written report
Aims and scope
Existing injection projects
Injection options
Representative analyses
Effect of fiscal terms
Case studies
Regulations
Conclusions /recommendations

This presentation
Aims and scope
Existing injection projects
Injection options
Representative analyses
X
Case studies
X
Conclusions &recommendations

資料626

Aims & scope

資料627

Aims
(A)To assess the techno-economic feasibility of
reducing CO2 emissions resulting fromnatural gas production in South-East Asia
through the application of CCS
technologies, specifically by re-injecting
the gas into subsurface geologicalformations.
(B) To promote awareness, build capacity anddevelop human capital in the discovery of
CCS.
資料628

ScopeA Costs of transporting and storing CO2 fromnatural gas discoveries in SE Asia.
B Excludes CO2 separation from natural gas.
C Potential for CO2 injection for enhanced oil
recovery (EOR), enhanced gas recovery(EGR).
D Coverage – Analyses of Brunei, Indonesia,
Malaysia, PNG, Thailand, Vietnam.
資料629

Existingprojects

資料630

Existing projects (not an exhaustive list)
Sleipner

Snøhvit

In SalahWeyburnMidale(EOR)

EconomyNorwayNorwayAlgeria

CanadaAustralia

Basin

North Sea

Hammerfest

AhnetTimimoun

Williston

Barrow SubBasin

CO2
injection
rate in Mt/yr

1

0.7

1

2.8

2.7 to 3.2

Number andtype ofwells

1×
1,250 mhorizontal

1 vertical

3×
1,000 mhorizontal

650
production& 289
injection

9×vertical

資料631

GorgonEOR – existing projects
As at 2008, there were 123 EOR projects
worldwide based on CO2 injection (mostly
USA).
Represents less than 0.5% of total crude oil
production.
An average of 18 Mtpa has been injected over4 decades (equivalent to the emissions fromfive-to-six 500 MW power stations).

資料632

Injection options

資料633

Storage possibilities
Saline formations- Storage only. Significant capacity? Needs
evaluation.
Producing oil and gas fields- Enhanced oil recovery - niche conditions.
- Enhanced gas recovery – needs research.
Depleted oil and gas fields- Storage only. Limited capacity?

資料634

Representative analyses

Approach

資料635

Scope of analysis (mostly offshore)
Methane export
Pre-treatment
CO2 compression

CO2 removal

CO2 pipeline

Scope of analysis

資料636

Representative case net cash flow analyses
A. Before fiscal effects (this presentation).
B (In report). After fiscal effects of –Production Sharing Contract (PSC) terms
Royalty-tax terms
C. Mostly offshore

資料637

Representative analyses

Methodology&
assumptions
資料638

Representative case assumptions
Exploration and appraisal costs not included.
Sources = representative gas discovery nearby.
Sinks from APEC study by Newlands & Langford.
Published reservoir properties for each site.
Sales gas contains methane and some CO2.
Injected gas contains CO2 and some methane.

資料639

Representative case assumptions/methodology
Estimate capital, operating, end-of-project costs
Costs in US$2010 terms.
CO2 avoided = CO2 injected less CO2 emitted.
Use CO2-e avoided (methane and CO2 injected).
Project life = 25 years.
Discount rate = 7% real.
Best estimates only – no uncertainty analyses.

資料640

Results ofrepresentative
analyses
資料641

Cost of transport and injection
Terumbu, E. Natuna
Bampo Oligocene, N.…
Cycle V, Baram Delta
Peutu, N. Sumatra
Pattani, G. of Thailand
Nam Con Son
E Group, Malay
Kembelangan, Bintuni
Miocene Delta, Kutei
Batu Raja, NW Java
Talang Akar, S. Sumatra
H Group, Malay
I Group, Malay
J Group, Malay
Talang Akar, NW JavaD Group, Malay
K Group, Malay
L Group, Malay
Sihapas, C. Sumatra
Pematang, C. Sumatra
All cases
0

Extra power
Compression
Pipelines
Injection
On-Costs

31
67
Specific cost of CO2-e avoided (US$/t)
5 資料642 10

15

20

25

30

Total costs
0.9
0.8
0.7
0.6
0.5
0.4
0.3

Present value of costs(US$ billion)

1.0
Best
fit

0.2
0.1

Annual CO2-e injected (Mt/yr)

0.0
0.1

1

10
資料643

100

Economies of scale
Cost of CO2-e avoided (US$/t)

70
60

Best fit

50
40
30
20
Annual CO2-e injected (Mt/yr)

10
0
0.1

1

10
資料644

100

1000

Effects of fiscal terms
Existing Production Sharing Contract
terms do not take into account CO2transport & storage costs andrevenues.
These could have a large effect on
economics as discussed in our report.
However, we do not yet know how CCS
will be treated.
資料645

Case studies

資料646

Case studies (injection component only)
Tangga Barat

NatunaCO2 content

30%

70%

Injection wells

4>90

CO2 injection

2.5 Mtpa>80 Mtpa

Project life assumed

15 years

75 years

Capital costs

US$220 MM>US$2,000 MM

Operating costs

US$4 MM /yr>US$180 MM/yr

Costs
excluding fiscal costs

US$14/t CO2e av >US$7/t CO2e av
資料647

Summary&
recommendations
資料648

Summary & conclusions
There are several existing CO2 injection
projects.
Potential in SE Asia for storage in saline
formations.
Limited potential for EOR.
Possible potential for EGR. Needs research.
Costs ignoring fiscal effects are from less than
US$5 to over US$60 /t-e avoided
Reservoir conditions and CO2 injection rates
are key determinants of the economics
資料649

Recommendations• Further studies should be based on close
collaboration with Governments andcompanies in APEC region.
• Assess exploration & appraisal costs andrisks.
• Further research into EGR.

資料650

Thank you

資料651

Report http:/publications.apec.org/publicationdetail.php?pub id=1021

資料652

CO2CRC Participants

Established & supported under the Australian Government’s Cooperative Research Centres Program

資料653

Interagency Task Force on
Carbon Capture and Storage
2010 APEC Clean Fossil Energy
Technical and Policy Seminar
Fukuoka, Japan
28 October 2010
Mr. Jarad Daniels
U.S. Department of Energy
Office of Fossil Energy
資料654

Task Force Background•

On February 3, 2010, the President established an interagency CCS Task
Force, co-chaired by EPA and DOE, with a report due in 180 days (August).

•

The Task Force has developed a plan to overcome barriers to widespread,cost-effective deployment of CCS within 10 years, including bringing 5-10
commercial demonstration projects online by 2016.

•

The group was charged with exploring incentives for commercial CCS
adoption and addressing any financial, economic, technological, legal,
institutional, social, or other barriers to deployment.

•

Led by DOE and EPA, more than 100 Federal employees from 14
Departments and Agencies drafted the report based on publishedliterature, individual input from more than 100 experts and stakeholders,and public comments.
資料655

General Report Outline• Role of CCS in Climate Policy• Status of CCS– Technology– Costs– Demonstration Projects– Regulatory Framework• Current Barriers for CCS Deployment– Market Failures– Regulatory Uncertainty– Public Acceptance• Conclusions and Recommendations
資料656

Role of CCS in
Climate Policy••

EPA analyses of cap-and-tradelegislation clearly show theimportance of CCS in achieving
climate goals while containing
costs.
A cap-and-trade system would
serve to make CCS costcompetitive for widespreadcommercialization.
If international offsets or otherkey technologies are notavailable, CCS becomes evenmore important as a cost
containment option.

120
100
80

GW

•

CCS Deployment under American
Power Act

60
40
20
0
2015

2020

2025

2030

EPA - Base case

資料657

2035

2040

2045

2050

EPA - No bonus allowances

CCS Technology Status•

Carbon Dioxide Capture and Storage (CCS) is a process consisting of theseparation of CO2 from industrial and energy-related sources, transportation toa storage location, and long-term isolation from the atmosphere.

•

Three elements of CCS:
– Capture & Compression– accounts for the majority of the CCS cost due to highcapital cost and energy penalties– Transport- requires infrastructure, pipeline, right of ways, limited by the economicsof transport distance.
– Storage- safety, permanence, liability, land and mineral access rights for geologic
storage.

•Technologies exist for all three components.

•

Current demonstrations focus on proving integrated operation and safe andeffective long-term storage at scale.

•

R&D focus is on developing advanced technologies to improve costcompetitiveness.

資料658

DOE-Supported
Demonstration Projects
Performer

Location

CaptureTechnology

Capture Rate(m tons/y)TargetFormation

Start
Date

Pre-Combustion Capture
Summit Texas
Clean Energy

Odessa, TX

Selexol

3.0

EOR

2014

Southern
Company

KemperCounty, MS

Selexol

2.0

EOR

2014

Hydrogen Energy
California

Kern County,
CA

Rectisol

2.0

EOR/Saline

2016

FutureGen
Alliance

Mattoon, IL

Selexol (see
note)

1.0

EOR/Saline

2015

•

DOE is providing approx. $4B
to support projects which:– Demonstrate theoperation of current CCS
technologies integrated
at scale.
– Develop improved CO2
capture technologies
and advanced power
generation technologies
to significantly reducethe cost of CCS.

•

There are other domestic
and international CCS efforts
that will contribute to thedemonstration of CCS.

Post-Combustion Capture

Basin Electric

Beulah, ND

Amine

0.5-1.0

EOR/Saline

2014

NRG Energy

Thompsons,
TX

Amine

~0.5

EOR

2015

American Electric
Power

New Haven,
WV

ChilledAmmonia

1.5

Saline2015

Leucadia Energy
Lake Charles

Lake Charles,
LA

Rectisol

4.0

EOR

2014

Air ProductsPort Arthur,
TX

Amine

1.0

EOR

2013

Archer Daniels
Midland

Decatur, IL

Amine

1.0

Industrial

資料659

Saline2014

Note: FutureGen will now be an
oxy-combustion demonstration
project

Regulatory Framework•

CCS projects can proceed under existing laws in the U.S.

•

U.S. EPA is developing requirements tailored for CCS, which will reduce
uncertainty for early projects and help to ensure safe and effective
deployment.
•
•
•
•

•

Safe Drinking Water Act (SDWA): Standards and requirements for permitting wells used
to inject carbon dioxide (CO2) for geologic sequestration.
Clean Air Act (CAA): Standards and requirements for reporting CO2 capture and geologic
sequestration.
Resource Conservation and Recovery Act (RCRA): Applicability of RCRA to CO2 streams
being sequestered.
Marine Protection, Research, and Sanctuaries Act (MPRSA): Requirements for subseabed disposal of CO2.

Experience gained from regulating and permitting early CCS projects will
inform the need for an enhanced regulatory framework for widespread
CCS deployment.

資料660

CCS TF - Findings•

There are no insurmountable technological, legal, institutional, or otherbarriers that prevent CCS from playing a role in reducing GHG emissions.

•

Lack of a carbon price is the key barrier to commercial deployment of CCS.

•

Existing Federal programs are being used to deploy 5-10 large-scale integrated
CCS projects to be on-line by 2016. However, early CCS projects facechallenges including the cost and performance of current generation
technology.

•

Federal agencies can use existing authorities and programs to begin
addressing barriers for these (and other) early CCS projects while ensuring
protection of public health and the environment.
– Supporting technology development– Providing legal and regulatory clarity– Supporting regulatory implementation– Addressing long-term liability and stewardship– Developing tools for public engagement and outreach
資料661

CCS TF – Findings (cont.)
•

•
•
•

•
•

R&D can enable commercial deployment of CCS by:– Demonstrating available technology to address integration issues,– Improving the cost and performance of 2nd generation CCS technology.
Projects can proceed under existing law, however, regulations need to be
developed and/or finalized and regulators need training and tools.
Increased coordination with all stakeholders (both Federal and State) will
enhance government’s ability to assist these projects.
Open-ended Federal indemnification should NOT be used to address long-term
CO2 storage liability. However, long-term liability and stewarship are important
issues which require further evaluation.
Public engagement and outreach is extremely important for CCS.
International collaboration complements domestic efforts on CCS and facilitates
global deployment.
資料662

Accelerated R&D•

Regarding accelerated R&D as one option to move CCS forward:“One option for improving the cost-effectiveness of CCS deployment is toaccelerate the availability of 2nd generation CCS technologies, and DOE iscurrently working to utilize Recovery Act funding for this purpose. This
accelerated program will focus on developing more efficient, lower capital
cost CCS technologies, and help to meet the President’s goal to enablewidespread, cost-effective deployment of CCS within ten years.”•

Note: $635 million of U.S. economic stimulus funds will be used by DOE toaccelerate CCS R&D

資料663

Recommendations:Technology Development• DOE and EPA should create a Federal agency roundtable to:– Act as point of contact for project developers and permitting
authorities.
– Create a technical advisory committee comprised of experts from thepower and industrial sectors, NGOs, State officials, and academia.
– Track CCS demonstration projects in order to identify any additional
research or regulatory needs.

• DOE, in coordination with EPA, Treasury, and USDA, should
track the use and efficacy of Federal financial support for CCS
projects.
• The Administration should continue to support international
collaboration that complements domestic CCS efforts andfacilitates its global deployment.
資料664

Recommendations:
Regulatory Development• By late 2010, EPA should finalize rulemakings under SDWA
and CAA and propose a RCRA applicability rule.
• EPA and DOI should immediately formalize coordination andprepare a strategy to develop regulatory frameworks foroffshore CO2 storage.

資料665

Recommendations:
Regulatory Implementation• EPA, in coordination with DOE and DOI, should develop
capacity building programs for underground injection control
regulators.
• EPA and DOE should identify data needs and tools to support
regulatory development, permitting, and project
development.
• EPA, in consultation with other agencies, should track
regulatory implementation for early commercial CCS projects
and consider whether additional statutory revisions areneeded.
資料666

Long Term Stewardship

Qualitative profile of environmental risk over time for a CO2 storage
operation (after Benson, 2007).
資料667

Recommendations:Long-Term Liability and Stewardship• By late 2011, EPA, DOE, Department of Justice (DOJ), DOI, andTreasury should further evaluate certain approaches toaddress long-term liability and stewardship.
• The Task Force examined 7 approaches to address long-term
liability including the current framework under existing laws.
– The Task Force agreed that near-term projects can move
forward under the existing liability framework and that
open-ended Federal indemnification, an option currently
under consideration, should not be used.
– Recommended approaches include:• Reliance on the existing framework;• Limitations on claims;• Creation of a fund for claims and site stewardship;
資料668 government after site closure• Transfer of liability to the Federal(w/contingencies).

15

Recommendations:Public Outreach• DOE and EPA should coordinate among Federal agencies,
states, industry, and NGOs to evaluate key concerns around
CCS in different areas of the US.
• Using this information, DOE and EPA should develop acomprehensive outreach strategy including:
1. A broad strategy for public outreach, targeted at the general publicand decision makers; and2. A more focused engagement with communities that are candidates
for CCS projects, to address issues such as environmental justice.

• DOE and EPA should establish a clearinghouse for publicaccess to unbiased, high-quality information on CCS anddevelop outreach tools for project developers and regulators.
資料669

What did others think?
• Google News: 300+ articles– New York Times: Federal Task Force Reasserts the Need for a Price on Carbon.
• “ The plain-spoken report describes the gantlet CCS must run to become commercial: forexample, explaining the technology to the public and clearing the regulatory thorns….It doesn’t
mince words about the most important policy: ‘The lack of comprehensive climate change
legislation is the key barrier to CCS deployment.’”– National Resources Defense Council’s (NRDC) George Peridas’s Blog:• “It appears that they struck the balance, solicited wide input, and reached soundconclusions…..The Task Force was careful not to paint a rosy picture….concise, well written andvery useful volume.”• “Those expecting the Administration to take the future of CCS in its hands and deliver a bright
future at one fell swoop through this report will be disappointed - but they should have been
looking at (and talking to) the U.S. Congress instead.”– Paul Browning, a GE Energy vice president:• “disappointed” with the report, which “missed a key opportuity to address the the mostserious impediment…..the current lack of market drivers that either lower costs or create
financial incentives for power companies to invest in advanced CCS technology.”
資料670

Thank you.

資料671

(13) セッション 5

資料672

Asia-Pacific Economic Cooperation
New Developments in Clean Coal and CO2 Reduction Technologies

APEC Clean Fossil Energy Technical and Policy Seminar 2010
Panel Discussion: Direction on CO2 Reduction in APEC Region
27 - 29 October 2010
Hilton Fukuoka Sea Hawk, Fukuoka, JAPANJapan’s Contribution to Cool Earth:
The Role of Clean Coal Technologies
Prof. & Dr. Takeo KIKKAWA
Graduate School of Commerce and Management
Hitotsubashi University
資料673

Contents

Ⅰ．Introduction
Ⅱ．Energy Conservation
Ⅲ．Technological Innovation
Ⅳ．“Top Runner Program”
Ⅴ. “Sector by Sector Approach”
Ⅵ．Concluding Remarks
資料674

Ⅰ．Introduction＊2 points in this presentation(i) How compatibility between environmental
protection and economic growth could be made,and(ii) How Japan should contribute to “Cool Earth”
on a long-term basis.

(i):Ⅱ and Ⅲ(ii):Ⅳ and Ⅴ
資料675

Ⅱ．Energy Conservation＊A “tradeoff” between affluence and global

salvation＊The tradeoff between affluence and global

salvation can only be resolved bypromoting energy conservation.

資料676

Ⅱ．Energy Conservation
Comparison of primary energy consumption per GDP
in each country/region
20.0

18.0

15.0

10.0

8.7

5.0
1.0

1.7

2.0

EU

USA

3.2

3.2

S. Korea

Canada6.0

6.0

ThailandMiddleEasterncountries

9.2
8.1

0.0
Japan

資料677

China

India

Indonesia

RussiaⅢ．Technological Innovation＊2008: 21 technologies to be prioritized in“Cool Earth—Innovative Energy Technology Program”＊6 technologies in Power generation/transmission
・High-Efficiency Coal Fired Power Generation
・Carbon Dioxide Capture and Storage (CCS)・High Efficiency Natural Gas Fired Power Generation
・Innovative Photovoltaic Power Generation
・Advanced Nuclear Power Generation
・High-Efficiency Superconducting Power Transmission
資料678

Ⅳ．“Top Runner Program”＊ Under the top runner system, automotive

mileage standards and electrical applianceenergy-saving standards are to be set atlevels that exceed the performance of themost efficient product on the market at thetime, in each product category.

資料679

Ⅳ．“Top Runner Program”＊ Energy efficiency improvement

TV sets using CRTs: 25.7% (FY1997～2003)
VCRs: 73.6％ (FY1997～2003)
Air conditioners: *67.8％ (FY1997～2004)
Electric refrigerators: 55.2％ (FY1998～2004)
Electric freezers: 29.6％ (FY1998～2004)
Gasoline passenger vehicles: *22.8％ (FY1995～2005)
Diesel freight vehicles: *21.7％ (FY1995～2005)
Vending machines: 37.3％ (FY2000～2005)
Computers: 99.1％ (FY1997～2005)
Magnetic disk units: 98.2％ (FY1997～2005)
Fluorescent lights: *35.6％ (FY1997～2005)
資料680

Ⅴ. “Sector by Sector Approach”（1）＊ The sector by sector approach would not cause

carbon leakage, because it aims to reduce CO2
and other greenhouse gas emissions per sector,
instead of per country.
＊Of the world’s total CO2 emissions from energy

sources, 26.0% are released from coal-fired
thermal power plants, 6.3% from iron and steel
production, 2.9% from cement production, and17.1% from road transportation.
資料681

Ⅴ. “Sector by Sector Approach”（2）＊ CO2 reduction

by diffusion of the best practice in Japan① coal-fired power generation: 1,347 M-ton/Y② iron and steel production: 340 M-ton/Y③ cement production: 180 M-ton/Y＊ ①：107％ ②；２７％ ③：14％
of Japan’s CO2 emission in 1990 (1,261 M-ton/Y)
資料682

Ⅵ．Concluding Remarks＊ In regard to the point (i), this presentation makes clear

the validity of energy conservation and technologicalinnovation. The former is concerning applies to short or
medium-term efforts, and the latter is regarding, to longterm strategy.
＊ In regard to the point (ii), this presentation introduces two

unique Japanese methods for reducing global
greenhouse gases, the “Top Runner Program” and the“Sector by Sector Approach”. The former is effective inthe residential, commercial, and transportation sectors,
and the latter is valid in the industrial sectors.

資料683

Direction on CO2 Reductionin the APEC Region
APEC Clean Fossil Energy Technicaland Policy Seminar 2010
Fukuoka, Japan
27-29 October 2010
John Karas
A/g General Manager
Low Emissions Coal and CO2 Storage Branch
Clean Energy Division
Department of Resources Energy and Tourism
資料684

WHY CCS?
• Global greenhouse gas emissions need to be reduced to 50% of2000 levels by 2050 to limit global temperature rises to 2°C,.
• Even more challenging for the Asia-Pacific region− Stronger economic and energy growth rates− Greater reliance on coal.
• Need large cuts in emissions from expanding coal use− High efficiency power stations are part of the answer− But wide spread deployment of CCS throughout the region isessential.
• With CCS, the real issue is timing.
資料685

CCS Timing• Different economies will have their own time frames, but delays in CCS
deployment will add to the cost of achieving long term greenhouseabatement objectives− IEA CCS Roadmap - 100 CCS projects needed by 2020.
• Australia needs CCS to be available for widespread deployment from 2020
− As an early mover we will incur the additional costs of immaturetechnologies− but the costs of delay for Australia can be much greater.
• Other economies (where the cost of delaying CCS deployment is not as
great) will benefit from lower cost mature technologies− But I expect that even these economies will need to position themselves
to be ‘fast followers’− They need to start now by putting in place the policies and strategies tosupport CCS deployment.
• International collaboration is supporting CCS capacity building andknowledge sharing.
• Opportunity for economies to draw on international expertise through APEC,GCCSI, IEA, CSLF.
資料686

The CCS Puzzle

Legislative
Certainty

Knowledge &Collaboration

Storage

CCS

Engagement

R&D

Demonstration
資料687

Community AcceptanceDirection on CO2 reduction in APEC region

Mr. Jarad Daniels
October 28, 2010

資料688

2010

資料689

2030

資料690

Gt CO2IEA Energy Technology Perspectives 2010: Global
energy-related CO2 emissions in the Baseline andBLUE Map scenarios
60
50

Other

40

Buildings
Transport

30

Industry

20

Other transformation
Power generation

10
0
2007

2030

2050

2030

Baseline

2050

BLUE Map

Global CO2 emissions double in the Baseline, but inthe BLUE Map scenario abatement across all sectors
reduces emissions to half 2005 levels by 2050.
資料691
4

Gt CO2IEA Energy Technology Perspectives 2010: Keytechnologies for reducing global CO2 emissions
60
55

Baseline emissions 57 Gt

CCS 19%50

Renewables 17%

45
40

Nuclear 6%

35

Power generation efficiency
and fuel switching 5%
End-use fuel switching 15%

30
25
20
15

BLUE Map emissions 14 Gt

105

WEO 2009 450 ppm caseEnd-use fuel and electricity
efficiency 38%

ETP2010 analysis

02010 2015 2020 2025 2030 2035 2040 2045 2050

A wide range of technologies will be necessary to
reduce energy-related CO2 emissions substantially.
資料692
5

Some U.S. Perspectives•

The Obama administration supports GHG emission reduction goals consistent
with mid-century climate stabilization.

•

The U.S. Congress has not passed comprehensive climate legislation that puts
a price on carbon.

•

As described in the President’s CCS Task Force report, U.S. EPA and U.S. EIA
analyses suggest that CCS could play a critical role in mitigating climatechange, but widespread deployment requires a price on carbon.

•

U.S. EPA regulations for large scale injection of CO2 are on track to be finalized
by the end of this year and will help provide regulatory certainty for CCS.

•

U.S. DOE is demonstrating current generation CCS technology, with ten (10)large scale integrated CCS demonstrations now planned to be on line by 2016.

•

U.S. DOE is developing lower cost 2nd generation CCS technology ready fordemonstration in the 2016 timeframe.

•Continued international collaboration on CCS RD&D is essential for our mutual
success!
– Technology, legal and regulatory frameworks, risk analysis, and public outreach.
資料693
6

Thank You

資料694
7

Direction on CO2 Reductionin the APEC Region
Dr. Frank Mourits
Natural Resources Canada

資料695

Observations of current
global situationWithout any action to curtail CO2 emissions, CO2 emissions in
APEC developing economies will drastically increase due tostrong increases in the use of coal for electric power generation

With no action, the objectives of keeping the atmospheric CO2
concentration below 450 ppm and the increase of the average
global temperature to less than 2 degrees C will not be met
 with unknown consequences!



Current approaches to come to a global accord to limit CO2 /GHG emissions do not seem to be progressingWithout limits on CO2 emissions and, thus, a price on carbon, it
is highly unlikely that industry, in a competitive market, will
voluntarily implement technologies that raise the cost of theiroperations and their products
資料696

2

While awaiting global agreement,
follow no-regrets approach

CCS is well-recognized as one of the key technologies that
could achieve large reductions worldwide (IEA)
 CCS falls within the purview of the EWG / EGCFE

But…need to bring down the cost of CCS (capture cost is 7080% of total cost) to a level close to where CCS may be
implemented and compete, even without a carbon price Developed economies to accelerate 2nd generation capture
technologies



APEC developing economies need to prepare for eventual
implementation of CCS (if storage opportunities are available) Requires building capacity and know-how, and thedemonstration of CCS technologies in their economy, withsupport, where appropriate, from developed economies
資料697

3

Steps that can be taken today, with support
from APEC and other organizations 1Host general CCS training workshops, followed by CCS subjectspecific technical workshops



Deliver on-site technical training in target economy and provide
training in universities, laboratories and other research institutes indeveloped economies



Carry out assessments of CO2 sources and potential storage
opportunities in each target economy (“Carbon Storage Atlas”)

Develop economy-specific technology roadmaps for CCSDesign, construct and operate pilot-scale CCS operations and design
full-scale facilities



Develop and implement legal and regulatory frameworks to enable
future commercial CCS operations

Develop and pro-actively implement public engagement strategies
資料698

1 GCCSI, IEA, CSLF, ADB

4

Progress of New Coal Policy for Global
Environment

October 28,2010
Masamichi Hashiguchi
Director
Coal Division, Natural Resources and Fuel Departmemt,
Agency for Natural Resources and Energy
Ministry of Economy , Trade and Industry
資料699

Contents
１．The Role of Coal among Global Energy Resources
２．Further Low Carbonization in Coal Fired Power Generation
３．Sustainable Coal Supply

資料700

1

Contents
１．The Role of Coal among Global Energy Resources
２．Further Low Carbonization in Coal Fired Power Generation
３．Sustainable Coal Supply

資料701

2

Energy Resource and Coal The stability of coal supply is higher than that of other fossil fuels as it is abundant with recoverable

reserves, and is widely distributed through the world.
 The cost of coal per thermal unit is low in comparison to oil and LNG.
 When burned, coal has the environmental drawback of emitting more CO2 per unit amount of heat thanother types of fossil fuels.
[Reserve-Production Ratio][Trend of Fuel Price (CIF Japan)]\/1,000kcal

150

0

120

(g-C/1000kcal)

826
billiontonnes

60.4
42.0

LNG

10

100

50

Steam Coal

12

122

R/P ratio

Oil[CO2 Emission per Thermal Unit]

1,258
billionbarrels

185
trillion
cubic
metresOilNatural Gas

Coal

8
6

2

20

0

0

'00

'02

'04

'06

Oil

Steam Coal

'08

'10

[Fossil Energy Reserves by Region]
100%

3.3
5.6
9.8

80%

60%

10.0

\/1,000kcal

8.3
4.8
4.0
7.9

Asia & Pacific29.8North America
Latin America

40%

3.9

59.9
41.0

Natural Gas

Source: BP Statistics 2009

AfricaEurope & Eurasia
Middle East

33.0

0%
Oil

1.8

Coal

0.2

：

４

：

３

[CO2 Emission per kWh]（g-CO2 /kWh）
1,200

8
34.0

20%

LNG

10

11.3

５

Source: based on “United Nations Framework
convention on Climate Change”

12
31.4

LNG

60
40

'98

Oil

80

4

'96

Coal

100

1,000

6

800

4

600

2

400

0

200

'08/01 '08/04 '08/07 '08/01 '09/01 '09/04 '09/07 '09/10 '10/01

Source: IEEJ

OthersBurning ofFuel0
Pulverized
Coal
Power

資料702

ＩＧＣＣ

Oil Power

LNG
Power

Source: 2nd workshop for the future of coal fired
power plant, “IGCC Demonstration Project”3

Role of Coal in Japan’s Energy Mix
 After the two oil crisis in the 1970s, natural gas, nuclear power and overseas coal have been progressively

introduced, achieving the best mix in energy balance.
 Coal share represents more than 20% of the total primary energy consumption.
 Coal-fired power generation plays an important role, representing around 25% of the generation mix inJapan.

[Primary Energy Demand in Japan]（10 18 J）
25

Oil

Coal

Natural Gas

Nuclear

Hydro[Composition of Power Generation Mix in Japan]

New Energy and Geothermal, etc.
22.76

（100TWh）

22.75 22.70

22.00
3.1%
3.4%

19.66

20

12.6%

11.7%

13.8%

16.5%

12.3%
15.92

New Energy 0.6％
Nuclear 30.6％
Geothermal 0.3％
LPG 0.3％
Oil 7.9％

8000

16.47
9.6%

14.38

15

10000

11.5%

6000

10.7%
12.42

LNG 26.0％

16.5%

17.5%

18.0%

21.3%

18.5%

16.8%

21.2%

4000

20.0%

10

2000
6.38

5 29.3%

69.9%

71.6%

56.0%

64.7%

53.6%

Coal 24.7％

49.0%

44.1%

55.4%

Hydro 9.1％

0
1970

1975

1980

1985

1990

1995

2000

2005

2006

（JFY）

55.9%

0
65

70

75

80

85

90

95

00

05 06

JFY

Source: Agency for Natural resources and Energy, “Outline ofElectric power Development”

Source: Agency for Natural Resources and Energy, “Comprehensive
Energy Statistics”
資料703

4

Role of Coal in World’s Energy Balance The share of coal accounts for one-quarter of total primary energy supply in the world and its consumption is

expected to achieve a 1.5 fold increases in 2030.
 Coal fired power generation represents 40% of total volume generated in the world and is projected to
doubled in 2030.
[Power Generation Mix by Fuel: World][Primary Energy Demand by Fuel: World]
35,000

Renewable
Hydro

発電電力量（TWh）

30,000

１.５
times

２７％

２９％

25,000

NuclearGas
Oil

20,000Coal

15,00010,0002 times

5,000

４２％

0
1990

Source: IEA, “World Energy Outlook 2009”

４４％

2000

2010

2020

2030

Source: IEA, “World Energy Outlook 2009”[Composition of Primary Energy Consumption in Major Countries (2007)] [Composition of Power Generation Mix in Major Countries (2007)]
0%

10%

20%

40%

50%

60%

70%

66%

China

United States

24%

Japan

22%

24%

31.5%
32.6%

27%

Oil

Gas

34%

Nuclear

Hydro

90%

0%

100%

3% 2.1% 10%
0.8%
27%

16%
25%

35%

18%

World Total

1.8%
0.7%
23%

39%

26%

Germany
United Kingdom

6%

45%

19%

EU

80%
18%

41%

India

Coal

30%

0.3%

China

0.3%

India

9% 0.9% 0.6%
4%
1.2% 0.8%
1%1.5% 6% 0.9%

EU

0.8%

Germany
United Kingdom

21%

8%
0.4%
0.2% 2%6% 2.2% 10%
0.6%

Biomass

Other Renewable

Coal

60%

70%

80%

14%

49%

Gas

1.7%

Nuclear

19%

26%

1.2%

42%

Oil

21%

22%

24%
28%

11%

9%

22%

42%
6%

21%

Hydro

Wind

90%

100%

1.0% 1.9% 15%
1.2%
8% 2.1% 16%

5%
1.8%

3.4%

35%

World Total

資料704

50%

68%

31%

11% 0.5% 7%

40%

49%
28%

39%

30%

81%

Japan

23%

Source: IEA, "World Energy Outlook 2009"& "Energy Balances of OECDCountries (2009 Edition)"

20%

United States

13%
14%

10%

0.1%

0.0%
1.5%
6%
2%
0.8%
2%
7%
0.3%
3.1% 3%

4% 6.2% 5%
0.5%
2% 3%
1.3%
2%
16%
0.9%

16%
14%

Solar

Other Renewables

Source: IEA, "World Energy Outlook 2009"& "Electricity information
2009"

5

The Position of Coal on the New Basic Energy Plan
1.Shift to low-carbon systems in coal-burning power generation
1-1 Further shift to low-carbon systems in coal-fired power generation in Japan
1-2 Shift to low-carbon systems in overseas coal-fired power generation

2. Measures for ensuring stable supply of coal resources
2-1 Frontier development and closer cooperation with coal-producing countries
2-2 Effective use of low-quality coal for developing the new and clean energy sources

資料705

6

Contents
１．The Role of Coal among Global Energy Resources
２．Further Low Carbonization in Coal Fired Power Generation
３．Sustainable Coal Supply

資料706

7

Promotion of the Low Carbonization of Coal Fired Thermal Power in the world
based on the technical transfer●Technology of coal-fired thermal power in Japan has achieved power generation efficiency of the world’s highest level and maintains its efficiency,
by using efficient technology (ultra-supercritical and advanced ultra-supercritical) and operation knowhow.
●Application of high-efficiency coal fired power generation technology operated in Japan to plants in the U.S. , China, India will reduce CO2
emissions by an estimated 13 billion tons. Many low-efficiency sub-super-critical coal-fired thermal power plants exist in most ASEAN countries.
ThermalEfficiency (Gross, LHV)
熱効率（発電端・LHV）
（％）
43

Japan

41

Germany

39
US

37

Australia

35
33

China

31

India

29
27

Japan

GermanyUS

Australia

China

India

25
1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005（Year）
INTERNATIONAL COMPARISON OF FOSSIL POWER GENERATION EFFICIENCY (ECOFYS) (2008)

Comparative example of coal-fired thermal power and aged
deterioration
Power generation edge thermal efficiency(%, HMV)
Takasago Coal-Fired Power Generation Plant Unit1, Unit2

Efficiency maintenance by proper operation and management

Decrease in thermal efficiency

Coal-fired power plant of Xs

資料707

The Federation of Electric Power Companies of JapanAt Asia PacificPartnership(APP), eachcountry was
shown the caseof Takasago
coal-fire power
generation as amodel plant,
and its results
were highly
evaluated.

Further Promotion of Low Carbonization and Zero Emissions
in Domestic Coal-Fired Thermal Power (1)(1) Development, demonstrations and introduction of highly efficient coal fired thermal power
Efficiency Improvement of
Coal Fired Thermal Power Plants
５４％ＵＰ

３６％ＵＰ

資料708
Source:“Cool Earth 50 – Energy Innovative Technology Plan”

9Further Promotion of Low Carbonization and Zero Emissions
in Domestic Coal-Fired Thermal Power (2)Verification of coal-fired power generation including CCS

Development of CCS towards zero emission coal-fired power generation
・ Implement full-swing verification tests of a consistent system for separating, collecting,transporting and storing CO2 emitted in coal-fired power generation, etc, in order to achievealmost zero CO2 emissions eventually by combining highly-efficient coal-fired thermal power
and CCS, and aim at the realization of zero emission coal-fired power generation.

Cool Gen Plan
Osaki Cool Gen Plan
Outline: Large-scale verification test for IGCC/CO2 separation& collection technology
Location: On the site of Osaki Power Plant of Chugoku ElectricPower (Osaki Kamijima-cho in Hiroshima Pref.)Scale: Amount of coal used 1,100 ton/day level (Output power
170,000 kw level)

Osaki
Point

Test run: 2016 to 2019 fiscal year (plan)
Main implementation entity: Osaki CoolGen Corporation
資料709(company invested by Chugoku Electric Power Co., Ltd. and ElectricPower Development Co., Ltd.)10

Scheme of International Corporation for Research
Ministry of Economy,
Trade and Industry(Organizations)

Foreign Country（Organizations）

Political Dialogue

SupportSupportInternational Corporation for
Research & Demonstration

Japanese
Company etc.

ForeignCompany etc.

※It is fine to build an international regulation.
資料710

11

3-3. Promotion of International Joint Verification Research with Australia
and Other Countries
Development and verification of CCS towards zero emission coal-fired power generation(1) Callide Oxyfuel Project
Joint Australia- Japan verification project where the existing Callide Power Station in Queensland inAustralia is converted into an oxyfuel system which can easily capture CO2 and emitted CO2 iscaptured and stored.
CO2 storagesite

Callide Power Station

Australia

Brisbane
Queensland in Australia (near Brisbane)(2) ZeroGen Project
Project where an IGCC station with a CO2 collection/storage function is constructed. Advanced by
ZeroGen Pty Ltd. in Queensland in Australia.
Commercial IGCC station with CCS. The coal gasification technology adopted in this project wasdeveloped by Japan.

資料711

12

Promotion of Low Carbonization
by Technology Transfer to Overseas Coal Fired Thermal Power Plants (1)Market size of 10 to 20 trillion yen/year. The capacity of power generation facility is expected to be double by 2030.
Regionally, notable demand expansion in Asia such as India and China.
Demand for highly efficient coal-fired power generation is expected to increase in advanced and emerging countries due to the necessity of global
warming prevention measures.

Russia5.3 trillion yen(52GW →
73GW)

EU

-10.5 trillion yen(200GW →158GW)

Middle East
2.8 trillion yen(5GW →
16GW)

North America

Japan
China

193.3 trillion yen(502GW →1275GW)-0.8 trillion yen(44GW →
41GW)

9.8 trillion yen(354GW → 393GW)

ASEAN

22.8 trillion yen(28GW →
119GW)

Africa6.8 trillion yen(41GW →
68GW)

South America

S.Korea＋Aus＋NZ
71.5 trillion yen(78GW →
364GW)

4.5 trillion yen(6GW → 24GW)

2.5 trillion yen(53GW → 63GW)

India

Outlook for introduction of coal-fired power generation in the world

The above amounts represent market size expected to newly appear by 2030.
(Estimation based on the assumption of 250 billion yen/GW)
The figures in brackets under each amount represent facility capacity in 2007 and資料712
predicted facility capacity in 2030.

* Created based on IEA World Energy Outlook 2009 reference scenario.

2007 actual2030 outlook(Unit: GW)* A considerable number of old facilities
is expected to be replaced in advanced
countries (North America, EU,
Australia, Japan, etc) but these are notincluded in the estimate.
13

Promotion of Low Carbonization
by Technology Transfer to Overseas Coal Fired Thermal Power Plants (2)1-2. Promotion of Low Carbonization by Technology Transfer to Overseas Coal Fired Thermal
Power Plants(1)Promotion of technology transfer of highly efficient coal fired thermal power technologies according
to the industrial structure of the partner countries(2) Export of systems with operation and management technology (O&M) of coal fired thermal power[Issues]
Incentive grants for CO2 credits, etc.
If Japan world's best standards of coal fired thermal power is applied in China, U.S. and India, it
can contribute to a CO2 reduction of 1,300 million tons
Mt- CO2▲387▲３８７ (mil
（百万㌧）
tons)

2000
(▲776 )(▲387)

＋▲７７６
＋▲776

（百万㌧）
(mil
tons)

＋▲１８４
＋▲184

（百万㌧）
(mil
tons)

About ▲
約 1,300▲１３億㌧
mil tons

1500

1000

1949
1562

2269
1493
ActualResults
572

500
(▲23)
269

246

ActualResults

State of Art
Introduction
Case

0

日本
Japan

ActualResults

State of Art
Introduction
Case
米国
U.S.

ActualResults(▲184 ）)
State of Art
Introduction
Case
388
388

State of Art
Introduction
Case

中国
China
資料713

インド
India

Source: IEA, “World Energy Outlook 2006”

14

Contributions in Other Countries by Japanese Technologies
and Products(Bilateral Offset Mechanism)
New mechanism for overseas contributions
Background○The CDM project currently governed by UN has limits due tobiased target areas and high business risks, etc.
○The Copenhagen Accord (COP15) offers new possibilities toapproaches made by each country independent of UN. U.S.
included a unique mechanism to recognize overseas
contributions by companies, etc into a bill.

New mechanism○ Japan established a new unique mechanism to recognize
GHGs reduction through diffusion of low-carbon
technologies and products which are specialties of Japan,such as highly efficient coal fired thermal power plants andatomic power plants as GHGs reduction by Japan throughpromises between two countries, etc. , which had virtually
not been approved of.

○By strongly backing efforts by private companies,
etc. accelerate the embodiment of the Hatoyama
initiative.

[Example of low-carbon technologies/products of Japan(and predicted GHGs reduction) ]○ Highly efficient coal fired thermal power plants
・ If Japanese technologies were applied to
all the coal fired thermal power plants in U.S.,
China, and India, the amount of CO2 which thewhole of Japan emits would be reduced inthese countries. (Approx. 1.3 billion ton)
○ Atomic power plants
・ The annual CO2 emission reduction effectof a single atomic power plant is approx.
6 million ton.

○Iron and steel
・ Japan maintains the cutting-edge technologies which can almost be usedpractically . If these technologies were applied globally, potential CO2
reduction would be approx. 340 million ton (which is approx. 26% ofemissions in Japan).
○Cement
・ Japan maintains the cutting-edge technologies which can almost be usedpractically . If these technologies were applied globally, potential CO2
reduction would be approx. 180 million ton (which is approx. 14% ofemissions in Japan).

(2) Transfer and diffusion of excellent low-carbon technologies and products of Japan(1) “International promise” between 2 countries, etc.
CO2
Emission
reduction
資料714(3) Appropriately reflected into the achievement ofdomestic targets of Japan

Developing
countries

Japan

Embody the Hatoyama initiative
Support utilizing ODA, JBIC and trade insurance, etc.

15

Contents
１．The Role of Coal among Global Energy Resources
２．Further Low Carbonization in Coal Fired Power Generation
３．Sustainable Coal Supply

資料715

16

Coal Reserves, Consumption and Trade○Japan is the largest coal importer in the world. More than 99% of its coalconsumption depends on foreign countries.
- Total traded volume of coal is around 900 million tons in the world,of which 20% is imported by Japan.
- Traded volume accounts for 15% of total production in the world. It
indicates that coal is consumed largely at the production site.
○Japan is dependent on Australia and Indonesia by 80% of total import.
○Steaming coal demand for power generation has been increasing with
rapid pace in the world, especially in China and India.

France21Mt
2.3%

Canada6%

Korea
100 Mt10.8%
Taiwan66 Mt
7.2%

Indonesia
19%

Russia
26 Mt
India
2.8% United States United
China Germany 60 Mt
Kingdom
6.5%
31 Mt
46 Mt 46 Mt
44 Mt
3.4%
4.9%
5.0%
4.7%

Source：IEA Coal Information

Coal Consumption
World Top 3
1 China 2.8 Bt
2 U.S.A. 1.0 Bt 73% of total
3 India 0.6 Bt

Vietnam 1%
U.S.2%
Others 0%
China 6%
Russia5%

Japan
186 Mt20.1%

Coal Import
923 MtCoal Reserves World Top 5
1 U.S.A.
2 Russia
78% of total
3 China
4 Australia
5 India

Coal Import by Country inJapan (2009 actual)

Global Coal Import Volume(2008)

Others298 Mt
32.3%



資料716

Coal Import（ Japan）
Australia
63%

Source：Ministry of Finance, “Tradestatistics of Japan17

Recent Overseas Situation regarding Securing of Coaland Response of Japan○Now that global coal demand expansion and growth of coal imports by China and India, etc are expected, further efforts
towards stable supply of coal is essential.
(Reference) Changes in coal imports and exports by China(Million
ton)(万トン）
15,00010,000

5,000

0
'99

'00

'01

'02

'03

'04

'05

'06

'07

5,000

10,000
輸入量
Imports

輸出量
Exports'08'09

Coal imports by China havebeen increasing since 2003 asits domestic coal consumption
increases.
Its exports drasticallydecreased by 50% and China
has been fully depending onimported coal since 2009.

Net
exports
純輸出量

15,000Measures for ensuring stable coal supply
1. Frontier development

2. Promotion of cooperation from coal producing countries○It is necessary to start working to secure new coal supply sources in○Strengthen multi-level relationships with major coal supply

countries such as Russia, Mongol and Africa as soon as possible.

countries such as Australia, Indonesia, China and Vietnam.

- Russia: Eriga coal field, Elegest coal field- Mongol: Tavan Tolgoi coal field- Southeastern Africa- Regular political dialogues- Supporting coal producing countries through geological
資料717
investigations, etc.

18

Japan’s Policy to Achieve Sustainable Coal Supply
Enhancing multilayerd relations with coal producing countries by holding policy dialogues.
＜Policy dialogues with main coal producing countries＞
Australia：Continuous Policy Dialogue in Coal
Indonesia： Continuous Policy Dialogue in Coal
Vietnam：Continuous Coal and Mineral Policy Dialogue
Mongolia：Continuous Joint Government and Private
Sector Mission on the Exploration of Coal・Mineral
Resources＜The joint government and private missions
to frontier countries＞
Mongolia：the joint mission for Tavan Tolgoi project in
Mar 2010.
South African Countries：the joint mission for
Mozambique in Oct. 2009.

Political Support for Coal Producing Countries
Coal Development○Corporation in coal developmentwith coal producing countries
・Oversea Geological survey(Indonesia, Vietnam, Mongolia, etc.)
・Information Exchange, etc.

○Training Project on Coal Mining
Technology
・Indonesia, Vietnam, and China.

Clean and Multiple Coal Utilization○Multipurpose Utilization of Low Rank
Coal・ Development and Introduction of
Improvement Technologies of Low Rank
Coal for Effective Use of Unused Natural
Resources○ CCT Cooperation
・Training Project on Coal Utilization
Technology, such as Coal Fired Power
Plants.

Support for privatecompanies○Potentiality Survey in
Coal Development
Financial support (2/3 of total
expense) for Japanesecompanies.

Financial Support

JBIC：Investment for resources
NEXI：Trade Insurance

Information Gatherings○Advanced Survey in Coal Development
資料718

Survey for infrastructure or mining technology of coal producing countries to achieve sustainable coal supply.

19

Efficient Utilization of Low-Rank Coal[Current Status]

Low-Rank
Coal

Half of the world's of
low coal reserves arecomprised-rank coals(brown coal, subbituminous coal)[Disadvantages]• Low combustion
efficiency due tohigh water content• Unsuitable for export
due totransportation cost
• Unlike steam coal,
they are unused[Advantages]• Suitable forgasification andliquefaction

Utilization of low-rankcoal as environmentfriendly clean fuelreplacing oil and natural
gas is essential forenergy security• Efficiency for low-rankcoal power generation isabout 30%.
• Emission per unit of over
1200g-CO2/kWh(normally 800gCO2/kWh in Japan)• Indonesia experienced asignificant decline innatural gas supply to
manufacturers including
for fertilizers due to thedecrease in natural gas
production• Demand for gasificationof unused coal is also
growing in Australia,etc.
• Consider export as anatural gas alternative
through conversion intomethane in the future• Indonesia: an oil
importer since 2004
• Demand for fuel oil
alternative throughliquefaction unusedcoal• Utilization of lowrank coal is essential
also for maintaining
export capacity forhigh quality coal

[Future Directionality]
Improve combustion
efficiency throughlow-rank coaldesiccation
technology• Improve combustion
efficiency to 35-40% bydesiccation• Active utilization of exhaust
heat to minimize loss ofenergy in desiccation
Coal

Gasified coal as
alternative to naturalgas

Ammonia
Synthesis

Gasification(fertilizers)

H2O
Methanation

CH4

Alternative todiesel oil by mixing
with water
資料719

Development oftechnology for
utilization
unused coal: JPY
260 million (2/3)

NH3、CH3OH

H2 + CO
Carbon Capture(CCS)

High-efficiency
brown coaldesiccation system
research:
JPY 150 million(2/3)

Research ontechnology for
production of clean
methane from lowrank coal: JPY 50
million (2/3)

International demonstration
including CCS(Victoria, Australia)

International
demonstration
for highefficiency coalflash pyrolysis(JPY 100 million;<=50% of Japan'scontribution)

Hydro-thermal reformation
technology for coalCoaldevelopment/utilization support projectfor coal producing
countries Within JPY
1.35 billion (2/3)

20Multipurpose Utilization of Low Rank Coal
2-1. Development and Introduction of Liquefaction and Gasification Technologies of Low Rank Coal for
Energy Supply and Demand Abatement(1) Development of liquefaction and gasification technologies according to the energy supply and demand structureof coal producing countries(2) Methane, DME etc., which occur from the gasification of the low rank coal mentioned above, can contribute to
the supply of clean energy to Japan in the future2-2. Development and Introduction of Improvement Technologies of Low Rank Coal for Effective Use of
Unused Natural Resources(1) Development etc., of improvement technologies such as dewatering and drying to improve the efficiency oftransportation and combustion

資料720

21

Thank you

資料721

(14) 閉会の辞

資料722

CLOSING REMARKS
Scott M. Smouse, Chair
Expert Group on Clean Fossil Energy
New Developments in Clean Coal and CO2 Reduction Technologies
APEC Clean Fossil Energy Technology and Policy Seminar
Fukuoka, Japan
28 October 2010
The theme of this seminar was “New Developments in Clean Coal and CO2 Reduction
Technologies.” We’ve focused on how to respond to the some of the challenges that coalfaces, not only in the APEC region, but everywhere that it is produced and used. Over the
past 2 days, we’ve heard from speakers from across the APEC region focusing on
developments related to advanced clean coal technologies. Carbon capture and storage
technologies – which are viewed as a critical component of any strategy for future substantial
CO2 reductions from the use of coal and other fossil fuels – featured prominently in our
program. Also, we heard from many APEC economies and India on their coal demand andsupply situations and coal policies.
The APEC region currently accounts for 40 percent of world population, 43 percent of world
trade, and 53 percent of the world’s gross domestic product. The region produces andconsumes more than 70% of the coal used annually around the globe, with more than 65% of
the coal consumed being used for power generation. About 90% of the increase in global coaldemand is in Asia. More than 50% of power generated in the region is from coal today – withthat number projected to remain almost constant through 2035. These numbers show thatcoal isn’t going away soon.
However, I think that we all agree that while today’s fossil fuel-based technology continues
to reliably power many APEC economies, it is increasingly evident that current technologies
can not ensure the continued long-term use of coal in the face of the climate change concerns.
The question is “Can the advanced coal-based energy systems that we are developing anddemonstrating now be commercialized quickly enough to provide enough clean energy atcosts that we can afford when we need it?” Our speakers have told us enough about theirresearch, development, and demonstration activities that I think we will be able soon toanswer that question in the affirmative.
The World Bank estimates that 2 billion people, a number that has hardly changed in the past
20 years, including some 800 million in Asia, do not have access to basic energy services,Those concerned about the impacts of climate change argue that continued reliance on fossil
fuels risks increased flooding and drought, failure of agriculture, shortages of drinking water,and sea level rise that will render many areas uninhabitable. And yet a plentiful supply ofenergy is an absolute must if we are to combat the worst of these effects and adapt to others.
Fossil fuels properly used alongside other forms of energy, and increased energy efficiency,
are needed if many countries are to bring adequate energy to those who either have no accessto commercial energy or whose supply of energy is so inadequate or unreliable that it cannot
even meet their basic needs.
The recent financial crisis has added a significant complicating factor. Even recognizing thestate of the world economy, however, we cannot afford to reduce support for energy projects
owing to the long lead time needed to bring new technologies to the market and to constructcommercial facilities.
In my opening comments, I noted that coal faces many challenges. A common misconception
is that because coal is a major contributor to carbon dioxide emissions globally, substantially

資料723

reducing or even eliminating coal-fired power generation is an easy first step. However, those
who understand the complex global energy situation and the hard linkage between energy andeconomic development recognize that coal, but with far lower emissions of carbon dioxide,
can be part of an effective mitigation strategy.
There are many conflicting voices, some arguing for and some against not only fossil fuels,
but also renewable energy sources, like wind, solar, and biofuels, for wide variety of reasons.
At the same time, the growing global environmental ethos is demanding more dialogue
because decisions made on these issues will significantly impact how energy will be
produced, delivered, used, and priced at all levels of our economies.
The general public has made its voice heard that the dialogue on why and how we use coalcannot be between just technologists and policy makers. Concerned individuals andorganizations are using the full array of tools at their disposal – the courts, the media, and theinternet – to be a part of that dialogue when they believe that their concerns are not being
addressed. Sound decisions by government and industry can best and should only be madethrough open communication on these complex issues involving all stakeholders.
I want to again remind you of the four major challenges that I have cited in each of the latest
several EGCFE seminars that we all face in moving to satisfy the growing demands for clean
energy across the APEC region, particularly as we work to ensure that coal can continue tounderpin our economic well being, These challenges are to: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 appropriate mechanisms exist to move these technologies into themarketplace at competitive 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 byusing the new more efficient, cleaner technologies that are available or will be availablesoon.
As we have heard, at this seminar and during previous seminars, that nations around theworld are engaged in the R&D and the full-scale technology demonstrations that will allow
us to transition from a fossil fuel-based world with substantial carbon emissions to some yet
to be defined lower carbon emission energy future. However, the reality is that fossil fuels
and existing technologies will continue to be the basis of growth for many APEC economies
for at least several more decades. Actions taken over the next decade to demonstrate anddeploy a variety of clean energy technologies, including CCS, will likely determine if we win
the battle against climate change and dictate what energy forms our children andgrandchildren and their children and grandchildren will use and what they will pay for it.
The Expert Group will continue to foster communication throughout the APEC region so that
economies can better consider the wide range of technical and policy options that areavailable today, and those 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 this week has discussed one or more salient issues that will affect theway that coal will be produced and used in the coming years. Each of these presentations
contributed to the dialogue on the complex technical, political, and business questions that

資料724

must be answered to secure coal’s role as an energy source in the region. The Expert Groupwill continue its efforts to help ensure that some of our more creative ideas are shared as
widely as possible, make it to the marketplace, and become part of our national strategies andpolicies. We welcome your comments on how we can better meet your needs, answer yourquestions, and how we can work together in the future.
Let me once again acknowledge the organizations that have supported this seminar. I want tothank our sponsors, especially the government of Japan, for successfully organizing andhosting this seminar. We would not be here without your support,
I thank all of the speakers and chairs for taking time out of their busy schedules to be with us,
Lastly, we would be remiss not to acknowledge the tireless support of the many people that
we all see but don’t always recognize…those who work behind the scenes at events like this
one to make them successful, including the local organizing team, especially JCOAL/JAPAC,
the management and staff of the hotel, and many others who’ve done such an outstanding job
in preparing for and executing this seminar. They’ve made my job easy. To them, I offer myspecial thanks.
Later today, during our annual EGCFE business meeting, we will begin 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 thevarious projects that I mentioned yesterday morning, as well as announcements on other new
projects that we are planning.
Each time there is a gathering of experts – whether in the laboratory, the classroom, or atconferences, workshops, and seminars such as this one – we move closer to solving thelingering challenges and developing the solutions that needed to ensure that coal is part of ourenergy futures. In closing, I thank each and every one of you for actively participating in thisseminar and wish you a safe trip home or wherever you are headed. I look forward to seeing
you at one of our future events.
Thank you.

資料725

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