平成 21 年度
海外炭開発高度化等調査「アジア太平洋石炭セミナー」
報

告 書

平成 22 年 3 月（独）新エネルギー・産業技術総合開発機構
委託先： 財団法人石炭エネルギーセンター

目
平成 21 年度

次

海外炭開発高度化等調査「アジア太平洋石炭セミナー」
本編

1. 要約 ··································································································· 1
2. 講演概要 ····························································································· 7(1)

開会セッション ············································································· 8① 開会の辞１APEC EGCFE 議長代行 ................................................................8② 開会の辞 2 韓国 KETEP 理事長 ......................................................................9③ 開会の辞 3 ｲﾝﾁｮﾝ市地球博覧会上級副事務局長...............................................9④ 基調講演 1JCOAL 会長(J-POWER 相談役) ....................................................10⑤ 基調講演 2 韓国ｴﾈﾙｷﾞｰ研究院(KIER)気候変動技術部門長 ..............................11(2)

セッション 1 APEC 域の石炭需給展望 (i) ········································· 12① 講演１中国の石炭需給展望...............................................................................12② 講演 2 ｲﾝﾄﾞの石炭需給展望..............................................................................14③ 講演 3 韓国の石炭需給展望..............................................................................15④ 講演 4 日本の石炭需給展望 ..............................................................................16(3)

セッション 2A 先進的 CCT (i) ························································ 17① 講演１韓国における循環流動床開発 ................................................................17② 講演 2 ｲﾝﾄﾞﾈｼｱにおける CWM 実証ﾌﾟﾗﾝﾄ CWM 開発 ....................................17③ 講演 3 GHG 排出削減先進的ｺｰﾙｸﾘｰﾆﾝｸﾞ技術の役割........................................18④ 講演 4 ｲﾝﾄﾞﾈｼｱにおける CCT 開発動向 ............................................................19⑤ 講演 5 微粉炭火力の新設/改善におけるﾌﾟﾗｽﾞﾏ点火 ........................................19(4)

セッション 2B CCS 開発動向 (i) ······················································· 20① 講演１CCS に関する IEA の見通し .................................................................20② 講演 2 APEC 途上国における CCS ﾚﾃﾞｨ発電設備のｶﾞｲﾄﾞﾗｲﾝ .........................21③ 講演 3 日本における CCS 政策及び開発動向 ...................................................22④ 講演 4 ｳｴｲﾊﾞｰﾝ CCS ﾌﾟﾛｼﾞｪｸﾄの最新状況 ........................................................22⑤ 講演 5 韓国における酸素燃焼ﾌﾟﾛｼﾞｪｸﾄ動向 ....................................................23(5)

セッション 3A 先進的 CCT (ii) ····················································· 24① 講演１NEDO における CCT 推進活動.............................................................24② 講演 2KIER の石炭液化ﾌﾟﾛｼﾞｪｸﾄ動向及び展望 ...............................................25③ 講演 3 火力発電と CCS ﾌﾟﾛｼﾞｪｸﾄの評価としての経済手法 .............................25④ 講演 4 韓国における IGCC 開発動向 ..............................................................25⑤ 講演 5 豪州の CCT・CCS 開発動向 ................................................................26(6)

セッション 3B APEC 域における石炭需給展望 (ii) ····························· 27① 講演１世界の石炭需給動向...............................................................................27② 講演 2 ﾀｲの石炭需給展望 .................................................................................29

③ 講演 3 米国の石炭需給展望..............................................................................29④ 講演 4 ﾏﾚｰｼｱの石炭需給展望.............................................................................32(7)

セッション 4 APEC 域における石炭需給展望 (iii) ······························ 33① 講演１ｶﾅﾀﾞの石炭需給動向...............................................................................33② 講演 2 豪州の石炭需給展望..............................................................................36③ 講演 3 ﾌｨﾘﾋﾟﾝの石炭需給展望 ..........................................................................40(8)

特別講演 1 韓国における気候変動に関するｴﾈﾙｷﾞｰ政策 ························· 41(9)

特別講演 2 韓国における CCT 遂行のための障害物と成功への道············ 42(10) セッション 5 CCS 開発動向 (ii) ························································ 43① 講演１韓国における CCS 研究動向..................................................................43② 講演 2 米国ｴﾈﾙｷﾞｰ省における CCS 開発動向 ...................................................44③ 講演 3 世界 CCS 研究所最新動向 .....................................................................45(11) 2009 ｾﾐﾅｰ最終纏め-ｾﾞﾛｴﾐｯｼｮﾝを目指す日本のｸﾘｰﾅｰｺｰﾙ政策····················· 45(12) 閉会の辞 ······················································································ 46
3. テクニカルツアー概要 ··········································································· 47
4. 結果取纏め ·························································································· 50(1)世界の石炭需給動向 ······································································· 51(2)

APEC 域の石炭生産及び消費動向 ····················································· 54(3)

アジア地域における石炭消費及び生産予測 ·········································· 60(4)石炭の輸出入 ················································································ 62(5)APEC 域における CCT 開発動向······················································· 66(6)

APEC 域における CCS 関連技術開発の現状 ········································ 69(7)

まとめ························································································· 72

資

料 集

1.

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

講演資料 ····························································································資料 6(1) 開会セッション ·············································································資料 7(2) セッション 1 ················································································資料 23(3) セッション 2A ··············································································資料 114(4) セッション 2B ··············································································資料 229(5) セッション 3A ··············································································資料 321(6) セッション 3B ··············································································資料 365(7) セッション 4 ················································································資料 427(8) 特別講演 1 ···················································································資料 515(9) 特別講演 2 ···················································································資料 538(10) セッション 5 ················································································資料 552(11) 2009 ｾﾐﾅｰ最終纏め-ｾﾞﾛｴﾐｯｼｮﾝを目指す日本のｸﾘｰﾅｰｺｰﾙ政策·····················資料 622(12) 閉会の辞······················································································資料 637

本 編

１． 要約11. アジア太平洋石炭セミナー要約
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。
現今の石炭需給の逼迫と石炭価格の高騰を鑑み、今回世界で最大の石炭輸入国である我が国、及び我が国に次ぐ第二の石炭輸入国である韓国において石炭消費国から見た石炭セミナーを開催することは、大変重要な意味を持つと同時に、石炭を取り巻く情勢や課題について
石炭セミナーを通してアジア太平洋地域間の共通認識を持ち協調を図ることは大変有意義である。
尚、16 回目となる今年度は、平成 21 年（2009 年）10 月 12～14 日にかけて大韓民国インチョン市にて開催した。
１． 開催日時
平成 21 年 10 月 12(月)～14 日(水)２． 開催場所
大韓民国インチョン市ソンド・コンベンシア（Songdo Convensia）
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)
大韓民国 知識経済省(MKE=Ministry of Knowledge Economy)
後援・ 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)
・ 独立法人新エネルギー･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）

・ 韓 国 エ ネ ル ギ ー 技 術 評 価 機 構 (KETEP=Korea Institute of Energy Technology
Evaluation & Planning)・ イ ン チ ョ ン 地 球 博 覧 会 実 行 委 員 会 (IGFFOC=Incheon Global Fair & Festival
Organizing Committee)
・ 韓国エネルギー研究所(KIER=Korea Institute of Energy Research)
４． 参加者数等
参加者数：講演者･聴講者あわせて計約 213（登録は 240 名）
参加国：日本、インドネシア、米国、カナダ、マレーシア、タイ、フィリピン、韓国、中国、豪州、インド、フランス、（計 12 カ国･地域）（台湾、ロシア、ベトナム；欠席）

５． 内容(1) 全体テーマ“Cleaner Coal; Moving Towards Zero Emissions”（よりクリーンな石炭；ゼロエミッションを目指して）(2) プログラム骨子

2

2 日間に亘り行われたセミナーでは、各国の石炭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 12 日)
Opening Session 開会セッション
Session 1 APEC 域での石炭需給展望-石炭政策を含め(i)Coal Demand/Supply Outlook in APEC Region – Environmental
Friendly Coal Policy (i)Session 2-A 革新的 CCT(i)Advanced Clean Coal Technologies (i)Session 2-B CCS 研究動向(i)Carbon Capture & Storage (CCS) R&D (i)Session 3-A 革新的 CCT(ii)Advanced Clean Coal Technologies (ii)
Session 3-B APEC 域での石炭需給展望-石炭政策を含め(ii)Coal Demand/Supply Outlook in APEC Region – Environmental
Friendly Coal Policy (ii)
二日目(10 月 13 日)
Session 4
APEC 域での石炭需給展望-石炭政策を含め(iii)
Coal Demand/Supply Outlook in APEC Region – Environmental
Friendly Coal Policy (iii)
Session 5
CCS 研究動向(ii)Carbon Capture & Storage (CCS) R&D (ii)
Final Thoughts on the Seminar
Japanese Policy for Cleaner Coal; Moving Towards Zero Emissions
Closing Remarks：
三日目(10 月 14 日)
 Technical Tour：Yeongheung (ヨンフン)火力発電所見学(3) 概要 今回のセミナーに、APEC EGCFE Smouse 議長が、査証問題により米国を出国
できず、よって、議長本人から直接依頼を受けたカナダ政府代表の Mourits
博士が議長代行を務めた（尚、議長欠席は、昨年度に引き続き 2 回目）。
 開会式では、前述した議長代行の Mourits 博士により APEC EGCFE としての開会挨拶に続き、韓国政府エネルギー技術 評価機構（KETEP=Korea
Institute of Energy Technology Evaluation and Planning）Joon-Hyun Lee
理事長による歓迎挨拶、インチョン地球博覧会 Kab-Won Oh 上級副事務局
次長による歓迎挨拶、続き JCOAL 中垣会長及び韓国エネルギー研究院(KIER=Korea Institute of Energy Research)Jong-Nam Kim 気候変動技術研究部長による基調講演を行った。
 続き、各国の石炭政策及び需給見通しについて、第一日目午前の部では、中国、インド、韓国、日本の計 4 本が発表された。特に、日本からは、資源エ
ネルギー庁石炭課による日本の石炭政策が紹介された。第一日目午後の部では、タイ、米国、マレーシアの石炭政策及び需給見通しが発表された。また、
JCOAL から、世界、特に APEC 域での石炭の需給動向を発表した。第二日目には、カナダ、豪州、フィリピンの発表が行われ、計 9 カ国 11 本の石炭政策及び需給動向についての発表が行われた。


一方、革新的な技術の発表が、10 本、CCS 研究動向が 8 本発表された。

3



今回の特徴としては、IEA 本部から上級エネルギー技術専門家を招聘し、IEA
での CCS 研究動向の様子を得ることができた。また、豪州に発足された
GCCSI 本部から GCCSI の紹介と現状報告がなされた。



また、特別講演として、2 日目の午後に韓国から 2 本、気候変動政策、及び、
韓国の CCT を進める上での障害とその解決策について発表がなされた。



最後に、セミナーの最後の纏めとして、資源エネルギー庁石炭課長から、日本のゼロエミッションを目指した石炭政策が紹介された。

 閉会の辞は、APEC EGCFE 議長代行のカナダ政府代表の Morits 博士が、Smouse議長作成の辞に自らの感想を加え、閉幕した。

 日本からは、JCOAL 中垣会長が開会式で、日本を代表して基調講演を行い、昨今のエネルギー情勢を踏まえた上での APEC EGCFE の役割等について講演を行い、また、資源エネルギー庁長官官房渡部企画官から日本の石炭政策、
NEDO クリーンコール開発推進部平田主査からは NEDO の CCT 活動、
JCOALの櫻井専務理事からは世界の石炭需給動向、そしてセミナーの締めとして、資源エネルギー庁石炭課國友課長から、ゼロエミッション化を目指した日本の石炭政策が発表された。









各国の講演概要は下記の通り；
中国：生産は27.93億トン、年産1千万トン以上の大型炭鉱が坑内掘17、露天掘7鉱と大型企業化。石炭は基幹エネルギーで、深部採掘や高ガス炭鉱が多く、安全生産が重要。2009年では輸入超過状態、需要は29億トンであるが、2020年には38億トン。
インド：生産は5億トン、インド石炭公社と公営SCCLの寡占状態。経済成長は7.5％
でエネルギー需要増は年率7％。坑内19％であるが、国内生産計画の未達で需給ギャップが拡大し、輸入は59百万トン。社会の持続発展には、民間企業育成、探査、
外資誘致、ハイウォール採炭、CBM、地下ガス化、石炭液化、有効土地利用及び鉱害対策等の課題が山積。 APP選炭事業については米国西バージニア大から報告。
韓国：原子力への転換。石炭調達方針は供給安定のため長期契約の方向へ。
フィリピン：DOEは増加する需要に対応して国内炭生産の拡大を計画。
インドネシア：CCT 関連の事業が紹介。

 最終日には、韓国南東電力社所有の Yeongheund Thermal Power Station（ヨンフン石炭火力発電所）（1 号機 2 号機；800MW、3 号機 4 号機；870MW）の見学を 43 名で行った。3 号機 4 号機は、2008 年に完了したばかりであり、この発電所で韓国全体の電力需要の約 20%を供給している。尚、まだ 5 号機 6 号
機を 2010 年に建設開始予定である。
 セミナー終了後、2 日目の夕方に行われた APEC EGCFE ビジネスミーティン
グ（政府間特別会合）では、昨年度同様に、Smouse 議長は国際電話でミーテ
ィングに参加した。ミーティングでは、国際電話による Smouse 議長からの説明を基に、Mourits 議長代行が、各国からの参加者と議長との交信がうまくいくように補足説明等を入れ議事進行を行った。また、日本からは 3 本、提案がなされた。1 本目は、APEC 石炭・天然ガス需給見通し及び政策提言 20104

の策定(案)が提案された。これに関しては、APEC のルールに則り、提案書(プロポーザル)を作成する必要があるため、追って Smouse 議長から提案書の様式が送られ、文書の作成をすることとなった。2 本目は、2010 年の本セミナーを日本で開催したい旨の提案を行った。これに関しては、事前調べで中国も 2010 年にセミナーを開催した旨の情報があったが、中国代表からは中国はまだ詳細等詰めていないため、且つ、日本が開催を希望するのであればとの理由から 2010 年の開催国希望を延期することとした。よって、2010 年は日本（福岡）で開催する旨、各国並びに議長の同意を得ることができた。3 本
目は、議長と事前に調整を済ませておいた EGCFE の活動の活性化への対応策を提案した。昨今の状況から、EGCFE の活動が、特にアジアの発展途上国において低下していることを鑑み、日本からどのようにしたら活性化が図れるのか、また、共通基金が底をついてきている状況を鑑み、新たに基金を立ち上げようではないかとの提案がなされた。これに関しては、各国代表とも一度自国へ戻り、関係者で検討することを約束した。議長並びに議長代行から
は特に 3 本目に対する反論はなく、アジア各国からの反応を待つこととなった。
(4) 統括及び所感本セミナーには、石炭課から國友課長と渡部企画官に出席して頂き、セミナ
ー本体はもとより、各国政府代表によるクローズドのビジネスミーティング
においても積極的な提案をして頂き、大変有意義な会合を持つことができた。
尚、石炭課から提案された EGCFE の活動の活性化対策（含、基金対策）に関しては、議長及び議長代行とともにアジア各国へ引き続きフォローをしていく予定である。また、2010 年日本（福岡）での開催を進めるに当たり、従来以上に早い対策をとり、滞りなく開催が進むよう取り図る必要がある。
以上

国際会議場

國友課長講演

講演者関係者一同 photo session

Biz Mtg
5

photo session

見学会

photo session

ヨンフン石炭火力発電所見学会

6

２． 講演概要

7

2. 講演概要(1) 開会セッション
Opening Session
セッション議長（韓国）Prof. Hee Chan Cho, Seoul National University
Session Chair (Korea) Prof. Hee Chan Cho, Seoul National University
国立ソウル大学 教授 ヒー・チャン・チャオ博士

Opening Address 1 開会の辞 1
Mr. Scott Smouse, APEC EGCFE Chair
APEC EGCFE 議長 スコット・スマウス氏
Dr. Frank Mourits, APEC EGCFE Acting Chair
APEC EGCFE 議長代行 フランク・モーリツ博士
議長であるスコットスマウスが査証トラブルで出席できず、大変申し訳ない。議長に代わり、2 日間議長代理を務めさせて頂く。議長が用意した原稿を読み上げる前に、自己紹介させて頂く。カナダ政府天然資源総局で、主に CCS を担当しているフランクモーリツである。自分は、議長も存じている通り、この APEC EGCFE のカナダ代表を長年務めてきた。この度、議長代行を務めさせて頂くことは大変光栄に思う。
APEC EGCFE は、このセミナーを開催するに当たり、韓国知識経済省、また後援して頂く韓国
KETEP、KIER、インチョン地球博覧会事務局、また日本の NEDO、JCOAL-JAPAC に感謝申し上げる。
今回のセミナーのテーマは、Cleaner Coal ; Move to Zero Emissions だが、様々な温暖化問題に関する会合が同時期に開かれている。ピッツバークで数週間前に開かれた G20、先週バンコクで開かれた国連気候変動交渉会合、またコペンハーゲンで 12 月に開かれる国連の COP15 など。
ピッツバークでの G20 では、世界の金融状況が話し合われ、「Move toward Greener, More
Sustainable Growth」とのコミットメントが発表された。
近日、国連気候変動対策室 Yvo de Boer 事務局長が、途上国での技術開発適用やキャパビルのような地球規模での同意が必要な分野は着実に進捗している。
我々が、エネルギーや環境分野、経済発展にリンクしている問題をより低価格で解決しようとした
場合、再生可能エネルギーを含めた全てのエネルギーを使うこと、また省エネを実行すること、気候変動問題へ対応することが必要であると言われている。この課題は、今回のセミナーのテーマである「Cleaner Coal」に関連していると思う。
低炭素社会やニア・ゼロエミッションを目指す CCT の開発は、気候変動によって引き起こされる危険性を回避することになるはずである。
今週我々が議論を戦わすように、多くの国で大規模な CCS 技術の開発に取り組んでいる。EU でもこの 3 月までの間に、34 もの CCS に関するプロジェクトが実証されると公表されている。
例えば、米国でも、米国リカバリー・再投資法により CCS プロジェクトへ 34 億ドル投資されることとなっている。また、カナダでも、連邦政府はアルバータ州政府とともに、3 または 4 か所の CCS プロジ
ェクトに対し 30 億ドル投資している。豪州でも多くの CCS プロジェクトが発表されている。
以上説明した通り、我々はニア・ゼロエミッションに向かい開発と実証実験を地球規模で行っているが、まだ解決せざるを得ない問題は山積みである。

8

最後に纏めると、CCT システムを含む低炭素化社会を目指す技術は、地球規模で強く、持続的に、且つバランス良く取り組まなくてはならない。今週我々がここ韓国で多くの意見を聞き、我々の世代が反映するためにも、そして、クリーンな環境を楽しむためにも、ゼロエミッションに向かって
引き続きどのように石炭に取り組まなくてはならないか議論することが必要である。

Opening Address 2 (Korea) 開会の辞 2（韓国）
Dr. Joon-Hyun Lee, President, Korea Institute of Energy Technology
Evaluation and Planning (KETEP)
韓国技術評価機構 理事長 ジョン・ヒュン・リー博士

2009年APEC Clean Fossil Energy Technical and Policy Seminarをここ韓国で開催できたことに関して、韓国政府知識経済省（Ministry of Knowledge Economy）に代わって御礼申し上げる。この 3 日間のセミナーを有意義にするために、活発な意見の交換を望む。また、特に、この開会セッ
ションの議長である国立ソウル大学の Dr. Chao、APEC EGCFE の議長代行である Dr. Mourits、
2009 年インチョン市地球博覧会上級副会長の Mr. Oh、JCOAL 会長の Mr. Nakagaki、KIER の気候変動技術調査部局長 Dr. Kim に感謝申し上げる。我々は、今新しいチャレンジに挑戦していることに意義があると思う。持続的な開発を達成するためにも、我々のエネルギーは環境保全に接している。韓国政府は 3 つの選択に迫られている。2005 年レベルと比較して、2020 年までに 8%、0%、
またはマイナス 4%になることを迫られている。韓国政府は 5 つの温暖化問題にコミットメントしている。それらのゴールを目指して、韓国政府はエネルギー問題に取り組んでいる。CCT の開発研
究は、韓国政府としても需要な課題である。このセミナーのアジェンダや講演者の所属しているそ
組織名を見ても分かる通り、世界各国の課題・組織に及んでいる。これらの国々との情報交換をす
ることは、韓国政府にとっても参加者皆さんにとっても大変意義のあることである。また、将来の国際的な協力関係を構築する意味でも、このセミナーに参加することは大変有意義である。このセ
ミナーが、将来の石炭需給や CCT に関するガイドラインになるよう、期待する。

Opening Address 3(Korea) 開会の辞 3（韓国）
Mr. Kab-Won Oh, Senior Vice Chairman, Global Fair & Festival, Incheon
インチョン市地球博覧会 上級副事務局長 カブ・ウォン・オー氏

セミナーを開催するに当たり、歓迎の挨拶を簡単にさせて頂きたい。このインチョン地球博覧会ん
の期間に、エネルギー技術の開発に特化したこのセミナーが、ここで開催されることに対して御礼申し上げる。地球温暖化問題への対応としてのエネルギーの問題が、ここで議論されることは、大変素晴らしいことである。

9

Keynote Address 1 (Japan) 基調講演 1（日本）
Mr. Yoshihiko Nakagaki, Chairman JCOAL & Corporative Adviser,
J-POWER
財団法人石炭エネルギーセンター 会長・電源開発㈱ 相談役 中垣 喜彦氏

昨今のエネルギー情勢は今後とも不透明で、不安定な状況が続くと思われるが、中長期的には中国
インド等の新興国や途上国の根強い経済成長の拡大をベースに、エネルギー需要は確実に増加する。
エネルギー市場価格も再び騰勢に転じる可能性が高い。よって、エネルギー供給のセキュリティ確
保は、世界にとって重大な課題になる。
一方、温暖化問題では、12 月の COP15 において、2013 年～2020 年をターゲットととしたポスト
京都議定書となる温暖化ガス削減目標に関する国際的枠組み合意に向けた議論が予定されているが、各国特に先進国において取組みへの考え方に隔たりやギャップがあり、合意へは困難であると伺える。
日本でも、9 月に発足した民主党政権のもと、9 月 22 日に国連気候変動サミットにて、鳩山首相が2020 年断面で 1990 年比 25％の温暖化ガス削減を図るとの中期目標を発表し、この分野で日本が世界をリードしようとしている。
さて、石炭においてだが、始原的にも最も豊富で、経済的にも安定した化石エネルギーであるがゆえに、現在だけではなく将来的にもエネルギー供給を支える中核的な資源である。今年 6 月に日本政府（経済産業省）は、将来の石炭利用の基本的な在り方を論議した「クリーンコール部会」報告を公表した。この報告は、地球環境と石炭利用の両立共生を図る日本の道筋と役割を明確に示したものである。この中で、日本政府は、①日本のエネルギー政策は経済性、供給安定性、環境適合性の 3E をバランスよく同時に達成していくことが基本であり、このためにも、石炭は、クリーンな石炭利用を進めることが不可欠である、②日本の世界最高の高効率石炭火力発電技術を逐次海外へ移転投入することにより、世界における 3E の同時達成に大きな貢献ができる、③長期的にみて、日本の革新的な高効率石炭火力発電技術と CCS 技術との一体的な開発を進め、その成果を日本から海外へ展開する、という 3 つの取組をメッセージとして国民に発信した。これらの取組は、「Cool
Gen 計画」「Clean Coal for the Earth 計画」として提起された。
今、我々がなすべきことは、各国政府や国際機関に対して、正確な情報と意見を提供するとともに、将来の不確実性を十分に認識し、石炭のクリーン化とその活用をベースに、エネルギーの安定供給と地球環境の両立に向けた合理的で実践的な処方箋を準備することである。今世紀における世界経
済において、APEC 域のポテンシャルは最大のドライビングパワーであり、これを支えるキーは石炭である。
参加者皆さんの活溌な論議を通して、
このセミナーが実りあるものになるよう協力をお願いしたい。

10Keynote Address 2 (Korea) 基調講演 2（韓国）
Dr. Jong Nam Kim, Director, Climate Change Technology Division, Korea
Institute of Energy Research (KIER)
韓国エネルギー研究院（KIER）気候変動技術部門長
ジョン・ナム・キム博士

現在の韓国の石炭需給動向及び KIER における CCS 開発動向に関して、皆さんに紹介したい。
韓国のエネルギー輸入は年間 85 億トン（2009 年）となっており、世界第 2 位の輸入国である。よって、我々韓国は技術の開発に意欲的に取り組んでいる。その中でも我が KIER が取り組んでいる
CCT 開発動向及び CCS 開発動向について紹介する。
1) KIER の研究内容
・ガス化 １t of COAL/day 及び 10t of COAL/day
・流動層石炭ガス化 ・・・Low rank coal（Lignite）が対象
・部分流動層石炭ガス化・・・１t of COAL/day（2009 年に設置）
・間接石炭液化
石炭→ガス化→クリーニング→Ｆ/Ｔ合成→アップグレーディング→ディーゼル油、ガソ
リン
ここでは KIER 鉄の液化触媒を使用
・Low rank coal のアップグレーディング
流動層ドライヤー
30％以上の水分に対応（4500Kcal/㎏以下）
500 t of COAL/day までを狙っている。現在 50 ㎏ of COAL/day の段階
・粘結炭用の脱水技術（POSCO と共同）・脱灰（アッシュフリー）炭
0.1 t of COAL/day・・・本技術は solvent による抽出法
ガスタービンへの適用については神戸製鋼と共同研究
2) 二酸化炭素分離技術の開発
Post、Oxy、Pre について開発中
・Post： チルドアンモニア法 将来 2000Nm3/h（2012 年に）CO2 と SO2 の同時分離を狙っている。
Ｋ2CO3 による吸収
CO2 分離膜・・・シングルチャンネルゼオライト
・Oxy：0.1MW クラス設備にて試験中
・Pre：2009 年・・ラボ試験
2012 年～2020 年・・20～30MW デモ試験
2020 年以降・・・CCS に適用
・ケミカルルーピングも開発中 50kw コンバスタを設置

11

(2) Session 1 Coal Demand/Supply Outlook in APEC Region – Environmental Friendly Coal
Policy (i)セッション 1 APEC 域の石炭需給展望 －環境に考慮した石炭政策を含めてSession Chair (Canada) Dr. Frank Mourits, Senior Climate Advisor,
Natural Resources Canada (NRCan)
セッション議長（カナダ）天然資源総局 上級気候変動アドバイザー フラ
ンク・モーリツ博士

Speech 1 (China) 講演 1
Coal Demand/Supply Outlook in China 中国の石炭需給展望
Mr. Chen Qi, Director-General, Industry Coordination Department,
China National Coal Association (CNCA)
中国煤炭工業協会 産業調整部長 チェン・キ氏

・

中国は世界最大の石炭生産・消費経済である。石炭は経済性、クリーン、信頼性において第一の選択肢である基幹エネルギーで、生産の大部分は域内経済で消費される。最近の中国経済の急速な発展に伴い石炭、電力、石油の供給不足が顕在化、エネルギー安全保障と持続発展への障害となっている。エネルギー政策は国内市場に立脚し、石炭産業は要石となり、資源利用効率向上、安全生産、経済効果、環境負荷軽減が持続発展と共に重要である。

The Increasing Trend of China Coal Production (2000-2008)
27.93

25

产量（亿吨）

Output (Hundred million Ton )

30

19.92
20
15

22.05

23.73

25.36

17.22
14.55
12.99 13.81

10502000 2001 2002 2003 2004 2005 2006 2007 2008
年份 (Year)
13

・

・

・

2008 年の生産は 27.93 億トン、2007 年から 2.57 億トン増加した。炭鉱数は 14,000 あり、552 万人の雇用を生んでいる。炭鉱災害死亡者数は前年から 571 人減少し、3,215 人である。2008 年は雪害や台風などの異常気象とともに四川省では 5 月に大地震も発生し、石炭価格は上昇したが、後半には経済危機の影響で石炭価格は下落した。
石炭資源の確認資源量は 1 兆 1,804 億トン、埋蔵量は 1,768 億トンで山西、陜西、内蒙古、新彊、貴州で 81％を占める。しかし地質条件は複雑で炭層は深部であり、露天採掘は 6％にすぎない。採掘
深度は 300ｍ以浅が 36％、300～600ｍが 45％である。高ガス炭鉱が 22％を占め、炭塵爆発・自然発
火・出水・山刎ねの危険がある炭鉱が存在する。
石炭生産地は山西省、内蒙古、陜西省。企業では神華集団（2.81 億トン）、中煤集団（1.14 億トン）、
山西焦煤（0.81 億トン）で上位 10 社では 8.43 億トンを生産している。

12

・
・

・
・

昨年は韓国、日本、台湾省、フィリピンなどに 4,543 万トンを輸出した。
2009 年1～7 月では前年同期8.9％増加の 16.1 億トンの原炭を生産し、平均石炭価格は 434.81RMBである。炭鉱災害は 18.4％減少している。輸出は 1,292 万トン、前年同期 57％減少、輸入は 5,687 万トンで 128％の増加となっている。
予測によれば、2009 年の中国経済の石炭需要は 29 億トンであるが、2015 年には 35 億トン、2020 年には 38 億トンとなる見込み。
石炭供給に関しては、産業構造調整を進めている。2008 年産 1,000 万トン以上の企業は 36。年
産 1 千万トン以上の大型炭鉱が坑内掘 17、露天掘 7 炭鉱と大型企業化しているが、深部採掘や高ガス炭鉱が多く、安全生産が重要。神華の Bulianta 炭鉱は 2 切羽で 2,148.7 万トンを生産し世界最高水準にある。国内輸送インフラも鉄道整備中である。

Distribution of China Coal Resources
1:15,100,00010

表 石炭需給統計 （出所： IEA Coal Information 2009/ JCOAL Magazine :Mil.t)
2000 年
2004 年
2005 年
2006 年
2007 年2008 年2009 上期
1,231
1,956
2,159
2,320
2,549
2,761
1,356
1,215
1,886
2,099
2,305
2,543
2,760
55.1
86.6
71.7
63.2
53.1
47.4
11.67
2.2
18.6
26.2
38.1
51.0
45.6
48.27
52.9
68.0
45.5
25.1
2.1
1.8
△36.60
注：APEC 石炭セミナー2009 における中国統計とは異なる。

生産量
消費量
輸出量
輸入量

China’s Leading Coal Producing Provinces and Large Coal Enterprises in 2008
OrderbyOutputProvinces(Autonomous
Regions)

Output(HundredMillion ton)

Order
by
OutputLargeEnterprises

Output（Hundred Million
ton）

1Shanxi

6.55

1

Shenhua Group

2.81

2

Inner Mongolia

4.72

2

National Coal
Group

1.14

3

Shaanxi

2.12

3Shanxi Coking
Coal Group

0.81

4

Henan

2.04

4

Datong Coal Mine
Group

0.69

5

Shandong

1.34

5

Huainan Coal
Mining Group

0.61

6

Guizhou

1.18

6

Shaanxi Coal andChemical Group

0.60

7

Anhui

1.17

7

Longmay Mining
Holding Group

0.55

8

Heilongjiang

0.97

8

Lu’an Group

0.42

9

Hebei

0.89

9

0.41

10

Yunnan0.86

10Zhong Ping
Energy ChemicalGroup
Yanzhou Coal
Mining Company
LimitedIn Total

21.84

In total

8.43

0.39
14

13

Speech 2 (India) 講演 2
Coal Demand/Supply in India インドの石炭需給展望
Mr. KS Kropha, Joint Secretary, Ministry of Coal (MOC)
石炭省 次官補 KS クロハ氏

・
・

・
・
・
・

・
・
・
・
・
・
・

・
・
・

石炭はアジアにおける最も重要な燃料である。インフラや法制度の制約が低コスト資源の足枷で、高コスト構造が供給に影響している。
インド経済において、石炭資源量は 2,670 億トンで東部・北部を中心に全国の半数となる 14 州で産する。（生産方式は）81％が露天採掘で、19％が坑内採掘である。特徴としては高灰分、4500kcal/kg以下の低発熱量石炭である。2008/09 年度の石炭消費は 5.52 億トンで、原料炭は少なく、87.1％は燃料用である。石炭生産は 4.037 億トン（外に褐炭生産がある）、輸入量は 0.59 億トンに達する。
インド経済では今後 5 年間は年平均 7.5％の成長が見込まれ、エネルギー需要は年率 7％増加が見込まれる。インドの電化率は 50％未満で、電力へのアクセスが重要な課題。
2011/12 年度には追加的に 79GW の電力が必要であり、うち 72％は石炭火力である。
現在の電力構成の 75％は石炭で、電力部門が国内炭の 76％を消費している。その他、鉄鋼・セメン
ト・肥料・化学工業・製紙工業が石炭に依存している。
石炭需要は 2007/08 年度（～2008 年 3 月）で実績 4.68 億トン。その内、電力 3.67 億トン、鉄鋼 0.4
億トン、セメント 0.2 億トン。2008/09 年度は 5.55 億トン、2009/10 年度は 6.04 億トン、2011/12 年度には 7.31 億トンとなる見込み。
現在の石炭生産では、2007/08 年度実績が 4.57 億トン、この内で石炭公社 CIL 生産が 3.79 億トン。
2008/09 年度は 4.93 億トン、2009/10 年度 5.32 億トン、2011/12 年度でも 6.8 億トン。
しかし、2011/12 年度の生産計画は進捗が当初見込みより低く、需給ギャップは拡大する。
石炭輸入は 2007/08 年度実績 4,979 万トン、2008/09 年度は 5,900 万トン。
CIL 以外への民間資本導入に期待。201 鉱区、459.5 億トンの資源量を開放。
資源の有効活用、資源開発促進、鉱業操業の受容性拡大、効率。収益性改善を図り、経済成長、持続発展、収益率向上及び効率向上を目標にする戦略。
資源開発の促進では、探査、プロジェクト形成、外資誘致など。
探査分野では 2008/09 年度の試錐長 272km、CIL 炭鉱 473 炭鉱で坑内 279、露天 163、露天・坑内
採掘 31 炭鉱である。CIL は 17 選炭工場を操業、うち原料炭 11 箇所。19 の新規選炭工場が建設中
でその処理能力は 1.056 億トン。
露天採掘では CAD 設計、高能力設備の導入をすすめ、坑内は 300ｍ以深に豊富な埋蔵量があり、7炭鉱を開発中。露天採掘からのハイウォール採掘は重要。
深部石炭資源への非在来型開発（CBM や地下ガス化）。地下ガス化への政策指針策定。
石炭液化、閉山対策、インフラ整備支援などの政策。地域環境対策は重要

14

Speech 3 (Korea) 講演 3（韓国）Coal Demand/Supply in Korea 韓国における石炭需給展望
Mr. Jae Hyeok Jang, Deputy General Manager, Korea East-West PowerCo.
韓国東西電力社 副部長 ジャエ・ホン・ジャン氏

・

電力分野における石炭需要は、2008 年は 6,387.7 万トンで 2007 年の 5,515.2 万トンから増加した。
主要調達先はインドネシア、豪州、中国である。インドネシア・豪州の調達が増加、中国が減少している。
（ppt 4） 国別一般炭輸入 （単位：1,000t）
Thermal Coal Import by Countries
Country
China

2002
15,061

2003
18,142

2004
12,1062005
10,330

2006
8,587

2007
9,172

2008
6,931

Australia

12,893

12,984

16,88819,274

17,435

15,13521,996South Africa

0

0

0

0

130

302

1,083

Canada

1,418

742

280

417

811

1,112

1,482

Indonesia

8,004

8,021

13,207

14,981

20,241

24,847

26,120Russia

2,492

1,331

3,656

2,289

3,157

4,512

6,016

USA

336

171

431

365

291

71

249

TOTAL
40,204
41,392
46,56747,65750,65355,152
63,877・・ 鉄鋼業の石炭需要は 2007 年の 14 百万トンから 2008 年は 21 百万トンであるが、2009 年は 19 百万ト
ン程度の見込み。2010 年に 21 百万トンを回復し、以降は漸増し 2012 年には 25 百万トンまでとなる見込み。
・ 電力構成割合において、石炭・天然ガスが減少し原子力発電が増加する。石炭は 2009 年の 33％から 2020 年には 29.4％となる見込み。石炭火力は 2009 年 1 基 500MW、2014 年 3 基 2,740MW、2015
年の 3 基 3,000MW が運転開始。一般炭需要は 2016 年まで漸増して最大 7,860 万トンとなり、以降は2022 年の 7,040 万トンまで同レベルを維持するが、コスト問題から低品位炭が増加する見込み。
・ 電力価格も見直す。石炭の安定調達戦略として、新規の調達先、例えばカナダ、南アフリカ、米炭などへの分散化を図る。長期契約を指向しサプライヤーとの関係強化を図る。更に上流分野・炭鉱へ投資することで安定供給を図る。経済面では、調達価格の多様化、低品位炭導入、輸送距離に応じた輸送船舶の選択・大型化などを進める。
・ 原子力シフト・ GENCO による石炭調達。中国との価格交渉において日本向けより安価（0.38USD/ｔ）に 260 万トン確保し、中国以外からの調達などを進めた。
・ （DOE）原子力建設計画
・15

Speech 4 (Japan) 講演 4（日本）
Coal Policy in Japan 日本の石炭政策
Mr. Yoshitaka Watabe, Director for Coal Policy, Director-General’s
Secretariat, Agency for Natural Resources and Energy (ANRE), Ministryof Economy, Trade and Industry (METI)
経済産業省 資源エネルギー庁 長官官房企画官 渡部 義隆 氏

・
・
・
・
・

石炭消費は増加し、貿易量の 20％、1.8 億トンを輸入する世界最大の石炭輸入経済。国内炭は 130
万トン程度で自給率は 0.7％。
石炭の調達先は豪州 59％、インドネシア 18％で中国炭は減少している。
石炭火力は電力構成で 27％を占める。熱効率は世界最高水準にある。石炭を利用する産業は多様
な海外炭利用に対応し高効率利用と環境対策を実施。
日本の CCT を CO2 排出が多い、米国・中国・インドに導入した場合は 13 億トンの CO2 排出削減が可能。
引き続き、Zero エミッション石炭火力を目指した CoolGen と Clean Coal for the Earth による国際展開を図っていく。

Q（IEA）：GHG 削減策として、効率向上と CCS どちらか。高品位の石炭利用が高効率に必要とされているのではないかA（JCOAL中垣）：日本の石炭火力発電は世界最先端の効率で操業しており、普及により地球温暖化対策
となる。
・

16

(3) Session 2 – A セッション 2-A
Advanced Clean Coal Technologies I 先進的 CCT I
Session Chair (US) Dr. Chao Chen, Manager, Power Select, Maison
Worley Parsons
セッション議長（米国）ウォーレイパーソン社 電力調整部マネージャー
チャオ・チェン博士

Speech 1 (Korea) 講演 1（韓国）Development of the Circulating Fluidized Bed for the Energy
Technology in Korea
韓国における循環流動床開発
Dr. Dowon Shun, Principal Researcher, Korea Institute of Energy
Research (KIER)
韓国エネルギー研究院（KIER）研究主幹 ダウン・シュン博士
・・・・

最近の循環流動床技術
CFBC 技術研究紹介（設計・燃料種類・診断）様々な燃料を CFBC で燃焼試験。例えば、褐炭・
低石炭化度炭、RDF、バイオマス、廃棄物など市場では、省エネが課題。石炭利用の改善や新エネルギーが求められている。循環流動床ボイラは容易に商業化できる技術である。
新技術の統合は市場の必要性から生み出すことが出来るが、市場は経済性と適用可能な技術を求めている。

Speech 2 (Indonesia) 講演 2（インドネシア）
R&D on Coal Water Mixtures as Preparation of a CWM Demonstration
Plant in Indonesia
インドネシアにおける CWM 実証プラント CWM 開発:
Dr. Datin Fatima Umar, Dr. Bukin Daulay and Mr. Chiaki Suyama,
tekMIRA・・・・

CWM は流体であり、取り扱いは重油並みで石炭よりも容易であり、自然発火の虞もない。
CWM に関しては実験室レベルで日揮・tekMIRA により実験室レベルで開始され、商業化を目指している。
CWM のユーザーポテンシャルを地域分野ごとに実施した。2.45 億 m3/年の船舶用ディーゼル燃料の需要があり、多くの企業に適用可能なことが分かった。
重油や船舶用ディーゼル燃料の需要を満たすため、CWM は技術的・経済性に代替が可能である。
特に、低品位炭が賦存する南スマトラ、南カリマンタン・東カリマンタンにおいては、商業プラントが建設される必要がある。

17

・

CWM 商業化には、前段として年産能力 10,000 トンの実証機が建設される。最低年産 100 万トン（若しくは石炭フィード 2,500 トン/日）規模の商業プラントが 2013 年に開始されることが期待される。投資総額は 2.5～3.2 億 USD である。

Speech 3 (US) 講演 3（米国）Role of Advanced Coal Cleaning Technologies in Greenhouse Gas
Reduction
GHG 排出削減における先進コールクリーニング技術の役割
Dr. Roe-Hoan Yoon , Director, Center for Advanced Separation
Technologies, Vierginia Polytechnic University

・
・

・
・

APP 石炭鉱業タスクフォース・プロジェクト報告
インド石炭産業は、埋蔵量で世界 4 位、生産で 3 位、石炭はエネルギー消費の 53％を占める。2030
年には石炭消費は現状から倍増する。しかし、石炭品質は低く、灰分は 40～50％程度のため、熱効率の低下、輸送コスト増加、O&M コスト増加が課題であり、政府は、環境の影響が懸念される場合において輸送距離が 1,000km 以上の場合、石炭灰分は 34％以下としている。
石炭の確認埋蔵量は 985.93 億トン、資源量は 2,564 億トン。
灰分・水分が高くなるに連れて CO2 排出も増加する。

Ash and Moisture on CO2 Emissions

Impact of Improving Efficienecy

1%efficiency→
2-3% CO2 reduction→
40% reduction possible

Center for Advanced Separation Technologies

CAST

Center for Advanced Separation Technologies

図. 熱効率向上
・
・

・

・
・

熱効率を 1％向上させれば、2～3％の CO2 排出削減が可能となる。
South Asian Monitor,2009 他の報告によれば、インドの CO2 排出の 2/3 は石炭起源である。利用炭の品質向上、ボイラや石炭火力技術改善、送電網の高電圧化などによりCO2 排出を45％削減する可能性がある。
コールクリーニングに関する、APP 石炭鉱業分野プログラムにより、米国連邦予算 100 万 USD で、低コストでシンプルな乾式選炭を試験した。米国で実績のある Eriez エアテーブルを用い、比重 2.0 でサンプル炭を分離し良好な分離性を確認した。
国内価格は CV：6,200kcal/kg 以上の石炭で 25USD/ｔ、CV：4940～5600kcal/kg の石炭で 20USD/ｔであり、課題はコストである。
原料炭についても重液サイクロン DMS を用いた先進選炭技術実証プロジェクトを実施した。

18

CAST

・

先進選炭技術の導入により 40％程度の CO2 排出削減が可能である。移行経済においては選炭技術普及が地球温暖化対策に有効である。

Speech 4 (Indonesia)
R&D on Clean Coal Technologies in Indonesia
Dr. Bukin Daulay, Head, Agency of R&D for Energy and Mineral
Resources, R&D Centre for Mineral and Coal Technology(tekMIRA), Ministry of Energy and Mineral Resources (MEMR)

・
・
・
・

・
・
・
・

インドネシア経済におけるエネルギー鉱物資源省の役割
エネルギーミックスにおける石炭は 2005 年の 15.34％から 2025 年には 33％とする政策目標。
CT 導入はエネルギー政策を支援するもので、低品位炭利用、経済性、環境調和型のCCT が求められる。
UBC プロセスは、低石炭化度炭を脱水して発熱量 CV を向上する。スラリー脱水プロセスをベースに高品位炭を製造する技術。神戸製鋼高砂ベンチスケールプラントを出発点にして南カリマンタンのSatui で原炭供給 1,000tpd（UBC 製造能力 600ｔ/ｄ）の実証機を運転。商業機に向けた F/S を進める
予定。
石炭液化
石炭ガス化
CWM
インドネシア経済はエネルギー需要を満たすために石炭に依存する。関心分野は低石炭化度炭利用、改質・液化・ガス化・CWM などの CCT 商用化に強い関心がある。

Speech 5 (China) 講演 5（中国）Plasma Ignition Technology for New and Retrofit
Pulverized-Coal Power Plants
微粉炭火力の新設/改善におけるプラズマ点火
Mr. Zhang Yonghe, Manager, Beijing Branch, Yantai LongyuanPower Technology Co., Ltd.
Ms. Zhao Xin, Deputy Manager, Securities Department, GuodianTechnology & Environment Group Co., Ltd.

・
・
・
・
・

NOx コントロールと低 NOx バーナー
Plasma 低 NOx 燃焼システム
Plasma オイルレス発電技術
Plasma Dual-Scale 低 NOx 燃焼技術
セメントキルンへの適用例

19

(4) Session 2-B セッション 2-B
Carbon Capture & Storage (CCS)

CCS 動向Session Chair (Korea) Dr. Byoung Moo Min, Principal Researcher,
Korea Institute of Energy Research (KIER)
セッション議長（韓国） KIER 研究主幹
ビヨン・ムー・ミン博士

Speech 1 (IEA) 講演 1（IEA）
International Energy Agency Perspective on CCS
CCS に関する IEA の見通し
Dr. Keith Burnard, Senior Energy Technology Specialist,
International Energy Agency (IEA)
IEA 上級エネルギー技術専門官 キース・バーナード博士

・キーテクノロジーにより CO2 排出が削減される予想である。キーテクノロジーとしては次世代 PC や
IGCC があるが、現在の世界平均排出は 1110ｇ/Kwh であるが、2020 年には 665ｇ/Kwh となると予測される。これには CCS が不可欠である。
・世界の CCS プロジェクトは現在 Weyburn、Sleipner など 5 プロジェクトがあるが、将来的には次のような
CCS がチャレンジされよう。
2015 年：18 2020 年：100 2030 年：850 2040 年：2100
2050 年：3400
・ CCS は 2050 年には広い範囲で適用されよう。
電力：39.6％ ガス：8.4％ セメント：5.3％ 化学：3.3％
パルプ：0.2％ 鉄：10％
バイオガス：20.2％ など
・CCS へのチャレンジは R＆D の加速、CO2 サイトの探索、法的枠組み、PA、国際協力などであるが、最も重要なのは大規模デモテストを行い、そこから学ぶことである。
・ このためには、2010－2020 年に 1.5～2.5 ビリオンドルの年間投資が OECD 国以外へ必要。また
CCS は CDM への適用も必要である。
・ 次の 10 年が CCS にとって、実現するかブレークしてしまうか、クリティカルの期間となる。
・ 特に注目されるＱ＆Ａはなされず。

20

Speech 2 (Australia) 講演 2（豪州）
Guidelines for CCS-Ready Power Plants in APEC Developing
Economies (APEC Project Report)
APEC 途上国における CCS レディ発電設備のガイドライン
Dr. Amir Tadros, Project Manager, Energy Sytems, Aurecon
アルコム社 エネルギーシステム部プロジェクトマネージャー アムー
ル・タダロス博士・2008 年に G8 リーダーは 2010 年までに 20 の CCS プロジェクトを支援すると述べている。本プロジェク
トの目的は Capture Ready のガイドラインを作ることにあり、そのために適当なプラントを対象にケー
ススタディーをすることである。
なお、Capture Ready の定義はまだなく、各方面でいろいろ提案されているところである。
・ 検討対象とした石炭火力は、中国、インドネシア、マレーシア、タイ、フィリッピン、ベトナムのユニットとしたが、この発表では中国の場合を示す。
・ 現時点で中国で計画されている新設石炭火力の構成は次のようである。

・ 中国の地下貯留容量は大量にある。また今回のケーススタディーの対象となるユニットは 600MW～1000MW の範囲で 16 ユニットあり、貯留サイトとの距離は 0～25km のケースが多く、150～
350km の場合もある。
・ ケーススタディー対象は下記を選択した。
600MW 超臨界圧プラント： 24MPa、566℃/566℃ 燃料は上質瀝青炭
湿式脱硫、脱硝、EP 設置
検討条件：将来の炭素分離はアミン、チルドアンモニア
CO2 圧縮コンプレッサーは蒸気タービン駆動、吸収液の再生には、デレーティングを防ぐために新設補助ボイラを使用。
検討項目：プラントレイアウト、排ガス系統（CO2 分離、液化、精製）、蒸気・水系統、など
・ 今後は性能関連数値、改造コストの算出などを進める。
Ｑ： 吸収液の再生に新設補助ボイラを設置することにしているが、タービン抽気を利用する案もある。
経済比較は？
Ａ： 今回はデレーティングがないように検討したが、ガスタービンをトッピングに追加してその排熱を利用する案などいろいろある。今後検討比較することになる。

21

Speech 3 (Japan) 講演 3（日本）
CCS Policy and Development Status in Japan
日本における CCS 政策及び開発動向
Dr. Masato Takagi, Director, Tokyo Branch, Research Institute of Innovative
Technology for the Earth (RITE)
財団法人地球環境産業技術研究機構（RITE）東京事務所長 高木 正人氏

・日本の CCS ポリシーは 2007.5 の Cool Earth 50、2008.3 の Cool Earth Innovative Energy Technology
Program、2008.7.29 の Action Plan Low Carbon Society に示されている。
CCS コストのうち、将来の分離コストは現在アミン法で 4200 円/t CO2 であるが、2015 年の目標を 2000
円/t CO2 に置いている。2020 年での IGCC からの分離では 1000 円/t
CO2 を目指している。
・ RITE ではアミン法以外にもメンブレン方を開発中。
・ 日本 CCS 調査会社が 2008～2010 年で、IGCC からの CO2 を磐城沖に 13,000t/年で貯留する場
合のケースについて開始。また大崎 CoolGen として、170MW の IGCC 計画があり、2013 年建設開始、2021 年から CCS 開始の計画としている。
・ 日本の国際協力として、カライド酸素燃焼、GCCSI がある。
・ まとめとして、日本では CCS の大容量テストに進むこととしている。
・ 注目される Q&A は無し。

Speech 4 (Canada) 講演 4（カナダ）
Weyburn-Midale CCS Project Update
ウエイバーン CCS プロジェクトの最新状況
Dr. Frank Mourits, Senior Climate Advisor, Natural Resources Canada(NRCan)カナダ天然資源総局 上級気候変動アドバイザー フランク・モーリツ博士

・カナダ政府は GHG 低減に熱心であり、CCS はカナダのエネルギーと環境にとって必要な技術である。
カナダはオイルサンドからの CO2 排出とその CCS 対応が独特である。
・ CO2 分離にはプレ、ポスト、オキシのいずれも研究しているが、そのコストは最高の場合には$100～150 超/t CO2 が予想される。
パイプライン CO2 輸送：$25/ t CO2
貯留：EOR、ガス田、帯水層 $5/ t CO2
・ カナダは CO2 発生源と CO2 シンクの場所が近いことが特徴であり、また天然ガスからの Acid Gas
Re-injection の実績がある。しかし CCS コストが商業的に成り立つのかについて大容量の実績やCO2 パイプラインの実績がない。またパブリックアクセプタンスのこともある。
・ カナダの CCS には次の連邦ファンドが設けられている。
Program for Energy Research & Develop. $55M
Eco Energy
$151M

22

Budget 2008$250
Clean Energy Fund
$1B
アルバータでは大容量 CCS プロジェクトのために$２ビリオンが用意されている。
なお。2009．3 には 8 つのデモエンジニアリングスタディーが行われているが、これらの紹介がを順になされた。
・ カナダは GHG を 2006 年レベルで 2020 年には 20%減を、2050 年には 60～70％減が目標。2020年までに non-GHG Electricity を 90％とする。
・ まとめとして、カナダでは CCS が大きな目標となっており、その実現に向かって大きなチャレンジをしている。
・ 注目される Q&A はなされなかった。

Speech 5 (Korea) 講演 5（韓国）Status of Oxy-Fuel Combustion Project in Korea
韓国における酸素燃焼プロジェクト動向
Dr. Sung Chul Kim, Leader of Oxy-fuel Combustion Project, Korea
Electric Power Research Institute (KEPRI)
韓国電力研究所（KEPRI）酸素燃焼プロジェクトリーダー サン・チュ
ル・シン博士・ 韓国の CO2 排出量は世界で第 9 位、1990 年に比較し 98％増である。CO2 排出量の 25.7％は発電からの排出である。
・ CO2 排出削減に対し、３つのシナリオを設定。
2020 年の予想排出量 813Million tonCO2
シナリオ１ 642 Million tonCO2 まで低減（21.0％減）
２ 590 Million tonCO2 まで低減（27.5％減）
３ 569 Million tonCO2 まで低減（30.0％減）（具体的なシナリオ内容については明示なし。）
・ この中で 2002 年に天然ガスに対し、2006 年には石炭に対し Oxyfuel 研究がスタート。
第一ステップ：2007～2010 コンセプト研究
第二ステップ：2010～2012 オキシ石炭バーナーの基本計画
第三ステップ：2012～2015 詳細設計ならびに燃焼試験
ドーサンバブコックと研究開発。ボイラの基本設計は終了。
・ヨンドン発電所でデモ試験を予定。本発電所は 2013 年に運転終了予定し、2015 年にオキシに改造する。プラントロス 8％を目標とする。（本発表ではポストのプラントロスは 10％ある。これがオキシを採用した理由である。）
コメント（中垣会長）：CCS は最後の砦と認識しているが、CCS は多くのリスクを含んでいる。当社ではアミンによる CO2 分離テストをやっているがコストが高い。コストを低減する必要がある。CO2 輸送もそんなに簡単ではない。実用的な CO2 削減のためには、まず古い発電所からの CO2 排出を、まず、リハビリや効率上昇対策を行ってまず削減することである。
コメント（IEA Dr. Watson）：既設石炭火力の効率向上は確かに重要である。すべての発電所を最新のも23

のと取り替えれば大きな CO2 削減が可能となる。CCS については新技術でなく、技術上にも自信がある
ものである。ただし、100ｋｍのパイプラインは新技術であるが、既に Weyburn では 20 年、Sleipner も 10 年
運転経験をつんできて、リスクも小さくなってきている。チャレンジはあるが CCS はやらざるを得ない。

(5) Session 3-A セッション 3-A
Advanced Clean Coal Technologies II 先進的 CCT
Session Chair (US) Dr. Roe-Hoan Yoon, Director, Center for Advanced Separation
Technologies, Virginia Polytechnic University
Speech 1 (Japan) 講演 1（日本）
NEDO’s Activities for Clean Coal Technology
NEDO における CCT 推進活動
Mr. Manabu Hirata, Project Coordinator, Clean Coal Technology
Department, NEDO
NEDONEDO クリーンコール開発推進部 主査 平田 学

・日本では既に多くの USC は商用運転がなされており、最近の日本では 80％のシアである。USC の効率
は通常の蒸気条件の 2.5％のアップである。
・ 日本では勿来、EAGLE の二つのガス化炉が運転されており、ほかに A-USC もスタートしている。
このうち EAGLE については、NEDO-JPOWER の協業であり、既に Step 1 は終了し、Step2(2007～2009)に進み、CO2 の 99％回収可能性を得ている。
また、Large Scale Demo Test として Osaki Coolgen 計画がある。これは 170MW、石炭 1100t/day
で、2012 年から建設が開始され、2016 年から運転される予定である。
・ その他勿来 IGCC の CCS 計画、ハイパーコール、COG からのリフォーミング技術などが紹介された。
・ まとめとして、NEDO はエネルギー効率の改善にむけての R&D について努力していると締めくくった。
Ｑ（韓国の教授）：日本には大きな地震が発生するが CCS は大丈夫か？
Ａ：長岡での CO2 地下貯留試験中に大地震に見舞われたがリークが発生したり設備に損害を受けるということはなかった。
Ｑ：日本には CO2 地下貯留容量は十分にあるのか？
Ａ：RITE で調査しているが、150 ビリオントンくらいが実用的な容量である。

24

Speech 2 (Korea) 講演 2（韓国）KIER CTL Project’s Status and Prospect
KIER の石炭液化プロジェクト動向及び展望
Dr. Heon Jung, Center Leader, Clean Fossil Energy Research Center,
Korea Institute of Energy Research (KIER)
KIER 化石燃料研究所 センター長 フォン・ジュン博士

・韓国では石炭の間接液化を採用しており、将来的には石炭 10ｔ/日で、15 バレル/日の石炭液化油を生産することが目的としたプロジェクトを立ち上げている。
・ 現在は１ｔ/日の 30 気圧スラリフィードガス化炉にてテスト予定。近々にテストを計画している。鉄系の液化触媒を採用。
・ ガス化ガスクリーニングはフィルターを使用しているが、既存セラミックフィルターを新しいフィルターに変更して試験を実施。本フィルターの製造法は特許取得済みである。

Speech 3 (China/US) 講演 3（中国／米国）
EcoNomics-A Systematic Analysis Methodology and Tool for Fossil FuelPower and CCS Project Evaluation
Dr. Chao Chen, Manager, Power Select, Maison WorleyParsons
・火力発電と CCS プロジェクトの評価としての経済手法の紹介。

Speech 4 (Korea) 講演 4（韓国）Development Status of IGCC in Korea
韓国における IGCC 開発動向
Dr. Dal Hong Ahn, Leader of IGCC Project, Korea Electric Power
Research Institute (KEPRI)
韓国電力研究所（KEPRI）IGCC プロジェクトリーダー
ダル・ホン・アム博士

・韓国はクリーンコールテクノロジーの一環として IGCC＋CCS プロジェクトを立ち上げているが、その状況についての発表である。
特徴は高効率（39～42％、HHV net）、先進ガスタービンを使用することで 45～46％画実現でき、環境数値も SOx99.9%減、NOx25ppm で、CO2 の 90％の CCSが可能、フィードストックも石炭、バイオマ
ス、廃棄物、残渣油が適用できるなどがあるが、問題点としては高いイニシャルコスト、複雑なシス

25

テムといったところである。
・ 韓国の政府の電力への目標は、2011 年には新エネ、再生可能エネを 2.5％～7％導入することと、
2012 年までに 300MW IGCC 建設が掲げられている。
・ 韓国の IGCC は主契約者は韓国電力、サブは韓国ウエスタンパワー、ドーサン重工などである。
期間は 2006 年 12 月１日～2014 年 11 月 30 日の 8 年間を予定。ファンドは政府が 30％、参加者が 70％負担である。
・ IGCC 技術としては SHELL 炉としているが、製造は 90％以上をローカル化する。IGCC プロジェク
トは韓国の新たな成長エンジンとして期待されている。
Ｑ（中国）：石炭性状は？水分％は？
Ａ：設計は水分 15％としている。Low Rank Coal を考えているが、効率を重視してシステムを検討した。

Speech 5 (Australia) 講演 5（豪州）Australian CCT and CCS Development
豪州の CCT・CCS 開発動向
Mr. John Karas, Manager, Clean Coal Technology Section, Resources
Division, Department of Resources, Energy and Tourism (DRET)
豪州資源・エネルギー・観光省 資源部 CCT 課 マネージャー ジョン・カラス氏
・なぜ CCS なのかについて、IEA は 2050 年までに CO2 の 80％削減を提言しており、低炭素技術が必要になってきているが、このうちの 20％は CCS からとしている。
・ 豪州政府の CCS イニシャチブは、Clean Energy Initiative、National Low Emission Coal Initiative ま
た CCS Flagship Program などがある。豪州クイーンズランド州も大きな CO2 削減は CCS によるとしている。
例えば、CCS Flagship Program は$2.0 Billion で２～４の Industrial Scale CCS Project を考えている。
他にも同様のファンドを用意している。
・ 特に注目されるＱ＆Ａはなかった。

26

(6) Session 3-B セッション 3-B
Coal Demand/Supply Outlook in APEC Region – Environmental Friendly Coal Policy (ii)
APEC 域における石炭需給展望 －環境にやさしい石炭政策(ii)
Session Chair (Korea) Prof Hyung Taek Kim, Ajou University
セッション議長（韓国）亜州大学 ヒュン・タク・キム教授

Speech 1 (Japan) 講演 1（日本）
Coal Demand/Supply Outlook in the World
世界の石炭需給動向
Dr. Shigeki Sakurai, Senior Executive Director, Japan Coal Energy
Center (JCOAL)
財団法人石炭エネルギーセンター(JCOAL) 専務理事 櫻井 繁樹博士

・・

世界の石炭消費、価格動向、貿易動向、石炭の需給安定化の課題の 4 項目を説明
世界のエネルギー消費は現行政策のままの場合（参考ケース）では、2006 年の石油換算 117 億 toe
から年率 1.6％で増加し 2030 年には 170 億 toe となる見込み。増加分の 38％は中国、14％がインド
で化石燃料は引き続き構成の 8 割を占める。
石炭については、米国・英国などとともに多くの経済で石炭火力が増設され、電力構成の 41％から2030 年には 44％へ増加する。特に、インド中国において新設される計画である。
石炭は一次エネルギー消費の 29％を占めるが、アジア太平洋区域では 51％。2008 年の消費は 68億トン（33 億 toe）
石炭消費は電力用石炭を中心に増加し、2020 年 77 億トン、2030 年には 90 億トン。増加分の 8 割は電力向けである。

・・・

石炭消費量（百万トン）

EIA 石炭消費予測
10,000
9,000
8,000
7,000
6,000
5,000
4,000
3,000

米国
Japan
China
India
Total World

2,000
1,000
0
2006

2010

2015
2020
暦年

2025

2030

27

2006
China

2,344

America

1,009

India

500

Japan

179

Europe819

World total

6118

・
・
・
・
・
・

(2008)
Actual
2,760
1,026
583
186
794
6,766

2010

2015

2020

2025

2030

Annual
rate

2,825

3,167

3,583

4,059

4,429

2.7%

1,034

1,081

1,105

1,136

1,237

0.9%

544

595

640

683

751

1.7%

175

173

168

162

156

-0.6%

809

792

769

754

748

-0.4%

6,720

7,194

7,691

8,312

8,996

1.6%

世界の化石燃料起源 CO2 は 290 億トン、石炭はその 42％を占める。石油 38％、ガス 20％。石炭火力発電所からは 83 億トンが排出されている。
参考ケースでは 2030 年の CO2 排出量は 410 億トン、高効率利用と CCS が重要。
石炭の貿易量は 9.2 億トン。生産量の 16％に過ぎない。
現在は石炭輸出に関して豪州、インドネシアがキープレーヤー。今後の輸出ポテンシャル拡大が期
待されるロシア、南アフリカ及び中米の経済や国際企業の動向に注目すべき
石炭価格は 2008 年に最高値を付けて以来金融危機の影響で需要が減少し、下落したが、現在は安定している。
今後の需給安定化には政策課題が幾つかある。課題は多いが、生産拡大に比較して新規資源量の増加が少ないこと。利用技術の高効率化による消費抑制と未利用資源の活用が重訂課題である。

28

Speech 2 (Thailand) 講演 2（タイ）Coal Demand/Supply Outlook in Thailand
タイにおける石炭需給動向
Mr. Viroj Sivavong, Chief, Coal Management Department, Electricity
Generating Authority of Thailand (EGAT)
タイ国電力公社（EGAT）石炭管理部 主任 ビロージ・シバボン氏

・
・
・
・

・
・
・

タイ経済の石炭は褐炭から亜瀝青炭で、大部分は低発熱量である。
石炭埋蔵量は 13.72 億トンで、最大炭田は Lampang 地域の MaeMoh である。既生産量は 2.46 億トン程度で、年産は 1,800～2,000 万トンで推移しており、2008 年の生産は 1,805.6 万トン。
2008 年の褐炭消費は 1,866.8 万トンで 1,629.5 万トンが電力用で、174.3 万トン程度がセメント産業向けである。
タイ経済での石炭需要総量は 3,480 万トン、うち電力用が 2,140 万トン。2021 年には 4,800 万トンまで増加する見込み。このうち電力向けは 2,830 万トンである。電源開発計画 2007-Ver.2 では 2016 年～
2017 年に合計出力 2,800MW の石炭火力 4 基が運転開始する計画である。
石炭需要の増加に伴い石炭輸入も増加している。
天然ガスが最大エネルギーであり、電力供給はガス 72％、石炭 21.4％（2,734.5GWh）。電力構成では引き続き有力な燃料。
石炭火力の環境影響と社会受容性が極めて重要課題である。超臨界石炭火力、CFBC、CWM 等の
CCT について、石炭利用に伴う汚染物質排出は電力産業や産業分野へのCCT適用により低減できる。

Speech 3 (US) 講演 3（米国）
Coal Demand/Supply Outlook in US
米国における石炭需給動向
Dr. William Watson, Coal Team Leader, Energy Information
Administration (EIA), Department of Energy (DOE)
エネルギー省 エネルギー情報局（EIA）石炭チームリーダー ウィリアム・
ワトソン博士・・・［環境に優しい石炭］に向けた政策動向。ワックスマン・マーキー法はエネルギー・環境政策で、2005年に対し 2020 年 17％削減、2050 年 83％削減を目指すもので再生エネルギー基準、効率向上、排出量取引制度（C&T）などに関する法案であり、下院で 6 月末に可決した。現在は上院で更に 20％削減としたボクサー・ケリー法として審議中で、通過すれば両院協議会で一本化される。C&T は米国経済に導入されるため、石炭にお将来を見通す為にはタイムリーな議論である。C&T は Zero エミッ
ションに向けての動きで本会議の方向性とも一致する。
今日の米国は 70 億トン-CO2 を毎年排出している。C&T 制度のもとでは 2020 年に 50 億トン、2050
年には 11 億トンの排出量枠に制限される。適用範囲は電力産業、石油精製、石油輸入、ガス配送業などである。
毎年の国際的なオフセット 15 億トンを含み 20 億トンの排出量が相殺される。累積的な削減量は 2030

29

・
・
・
・

年には米国経済の排出量の 25％削減に相当する。
炭素税若しくは C&T において石炭は外の化石燃料より価格が上昇する。
CO2 に 50USD/ｔの価格がつけば石炭価格の上昇は 260％に達し、石油 18％、ガス 29％に比較すれば大きい。石炭価格上昇により大規模な燃料転換が予想される。
米国経済の石炭消費は 2030 年までに 20～80％減少する。
現状の政策に変更がない参考ケースの場合、石炭生産は年率 0.9％で増加するが、C&T 導入の場
合は減少する。基本ケースでは 70％低下するが、国際的な削減がなく技術進展も限られる場合、2030 年の石炭生産は現状レベルから 20～30％低下する。現在最も生産性が高い PRB の例で見ると、
今後 40 年間の内に C&T 導入により殆ど Zero 生産に至る。
U.S. Coal Production Alternate Cap/Trade Cases, 1970-2030
In cases with most constraining options, coal production cut by 60% by 2030
Basic

Zero BankHigh Offsets

No International

No Int/Limited

ReferenceHigh Cost

2,000

1,500

(Million short tons)
Reference

1,000

Basic
500

Projections

History
0
1970

1980

1990

2000

2007

2020

2030

8

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

石炭生産予測・ C&T 導入に伴う制約条件により石炭価格は 41USD/ｔ～191USD/ｔの範囲に変動する。
・ 電力分野以外の民生、輸送分野における二酸化炭素排出削減は電力に比較すれば小さい。電力需
要の減少は 2030 年の参考ケースから 4.1～14.7％となり、電力分野の排出削減に重要な役割を果たす。
・ 米国炭の行方をまとめると、技術開発とカーボンオフセットが温室効果ガス削減の原動力となる。
CO2 排出削減のコスト維持のため技術革新が必要で、政策誘導により転換が促進される。
・ 2030 年までに電力価格は現状ケースから 10～80％上昇する可能性があり、2030 年までに消費者エ
ネルギー価格は 60％上昇する可能性がある。
・ GDP への影響はエネルギー変動と価格許容性が鏡になる。GDP 成長は参考ケースに比較すれば何れの場合でも低下する。
・ 2030 年まで、排出削減は主として電力分野での低コスト・オプションを選択することで進行する。2030
年以降の輸送分野と商業分野での排出削減はより高コストとなる。電力分野においても追加削減は可能であるが 2030 年までの対策よりは高コストとなる。
・ 米国大陸での森林吸収はコストや空間的な問題から上限があるが、2030 年以降には検討対象となる可能性がある。アイデア競争（技術競争）により未来が開ける。

30石炭需給 （単位：百万トン）
2006
1,068

2007
1,053

2008
1,075

2009
1,059

2010
1,068

石炭消
費

1,017

1,027

1,026

1,011

1,034

電力
輸出
輸入

931
44.9
32.7
12.2

949
53.4
32.9
20.5

945
73.7
30.9
42.8

932
79
30

958
75
44

石炭生
産

2009-2010 は EIA 短期エネルギー見通し（STEO2009）
Coal Costs to Electricity Producers, 2030
(2007 dollars per million Btu)

$20
$18
$16
$14
$12
$10
$8
$6
$4
$2
$0

17.83
10.04
6.13

6.83
3.85 3.97

2.04 1.69 1.87 1.86 1.81 1.45 1.54cslstce asi
d
nk
n
et
na
e
B
Co
i te
Ba
ffs
io
h
er
o
im
f
O
r
g
at
L
i
e
e
/
n
h
t
H
R
r
Z
g
In
te
Hi
In
No
o
N
Coal Allowance Cost

13

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

図. 電力業における 2030 年の石炭コスト

図.生産見通し （出所：EIA 短期エネルギー見通し 2009）31

図．石炭消費増減率 （出所：EIA 短期エネルギー見通し）

Speech 4 (Malaysia) 講演 4（マレーシア）
Coal Demand/Supply Outlook in Malaysia
マレーシアにおける石炭需給動向
En Ahmad Johari Jaffar, Head, Market Operation Unit, Electricity
Supply Regulatory Department, Energy Commission, Ministry ofEnergy, Green Technology and Water (KettHA)
エネルギー・グリーン技術・水資源省、エネルギー委員会、電力供給規制部 市場管理ユニット 主任 アーマド・ジョハリ・ジャファー氏
・

・
・

・

・

石炭利用の基本法・政策は、環境政策 2002、燃料政策 2001、国家開発政策などである。石炭に関しては、石炭供給委員会が 2003 年に設立され、石炭火力への石炭供給監視を実施し、政府に諮問している。
電力設備容量は 24.608GW で石炭火力は、ガス 57％に次ぐ位置にあり、25％を占める。電力構成は、
総電力量 113,823GWh の 27.3％である。
石炭供給は、2009 年においてインドネシア炭 84％、豪州 11％、南アフリカ 5％。2010 年までの電力
用炭の需要は、半島部の 4 基で最大 1,900 万トン、設備容量は 7.2GW。東マレーシアにおいては 3
基 200 万トンで、0.53GW。マレーシアにおける石炭火力発電所は、7 箇所。今後は石炭の割合が増加する。
石炭需給への影響は様々な要因がある。例えば、中国・インドの輸入拡大、（港湾での）滞船、割り当て変更、（鉄道インフラでの）脱線、労務、油価上昇、採掘設備不足、剥土比上昇、品質低下、政府介
入、更には不可抗力もある。
マレーシア経済における石炭利用への影響要因は、ガス分野では資源枯渇による生産変化、深海域における探査・生産コスト上昇、価格上昇、政策変更。石炭分野は、輸入炭への依存、国内炭生産
停滞、品質の不適合、環境技術等である。

32

(7) Session 4 セッション 4
Coal Demand/Supply Outlook in APEC Region – Environmental Friendly Coal Policy (iii)
APEC 域における石炭需給展望 －環境にやさしい石炭政策(iii)
Session Chair (US) Dr. William Watson, Coal Team Leader, Energy
Information Administration (EIA), Department of Energy (DOE)
セッション議長（米国）エネルギー省 エネルギー情報局（EIA）石炭チ
ームリーダー ウィリアム・ワトソン博士

Speech 1 (Canada) 講演 1（カナダ）
Coal Demand/Supply Outlook in Canada
カナダにおける石炭需給展望
Mr. Kevin Stone, Senior Commodity Analyst, Mineral s and Metals
Sector, Natural Resources Canada (NRCan)
カナダ天然資源総局 資源メタル課 上級コモデティ分析官 ケビン・ス
トーン氏
・

カナダの石炭産業は年産 7,000 万トン強（原料炭が 4 割）の規模の生産能力があり、24 炭鉱のうち坑内採掘は 2 炭鉱あり、全体の雇用数は 5,000 程度。2008 年の生産量は 2008 年 6,800 万トン、出荷額
は 43 億 CND である。3,240 万トンと約 4 割が輸出向けとなり、2,650 万トン（56 億 CND）が原料炭として輸出される。鉄道・港湾の最大取り扱い貨物は石炭である。

Mines (24), Ports and Railroads

Canada’s Natural Resources – Now and for the Future・・・

カナダの一次エネルギー供給の 10.2％が石炭であり、石油35.3％、ガス 29.5％、水力 11.3％に次ぐ位置。
石炭火力は 21 箇所あり、電力の 15.3％を供給し、国内消費 61 百万トンの 90％を占め、5,310 万トンが消費された。
石炭資源は 87 億トン、確認可採埋蔵量は 66 億トンである。内訳は瀝青炭 35 億トン、亜瀝青炭 9 億トン、褐炭 22 億トンである。

33

・

カナダ経済は、世界でも中規模となる石炭生産者で 14 位。政府機関は天然資源省が管轄しており。
産業分野では石炭協会 Coal Association of Canada が団体として機能。
カナダは中部・東部において電力用石炭をアメリカ経済から 2,060 万トン輸入している。
2004 年 6 月以降、石炭資源開発分野では 6 炭鉱が開坑、2 プロジェクトが認可されている。現時 6 プ
ロジェクトが申請段階。全て稼働すれば 2012 年には 990 万トンが追加され 2015 年の生産は 8,000
万トンに達するが、増加分は輸出に振り向けられる。
カナダの石炭需要見通しは2009年の6,000万トンから漸減して2010年に5,900万トン、2011年5,600
万トン、2012～2013 年は 5,500 万トンとなる見込み。2014 年では 4,700 万トン（オンタリオ州では石炭火力が禁止される）
カナダ憲法では資源は地方の所有、海洋（海洋底）と北緯 60 度以北は連邦所有。
石炭はカナダにおいて広い地域に賦存し豊富な資源である。現状の埋蔵量で 100 年以上の量がある。持続可能な資源開発と CCT 開発と導入のもとでは石炭はカナダのエネルギー供給に重要な役割を果たす。
石炭は 2030 年に向けて成長していく資源であり、世界の石炭需要はカナダ炭を求めており、カナダ
は引き続き世界にむけて原料炭の供給者としてあり続ける。カナダには熟練技術者に支えられた成熟した石炭産業が存在する。

・
・

・

・
・

・

Canadian Export Forecast
Canadian Export Forecast
60

million tonnes

50
40
30

6

6

31

31

2010

2011

20

11

11

39

39

39

2013

2014

2015

7

8

39

2012

10
0

Coking Coal

Thermal Coal

Canada’s Natural Resources – Now and for the Future

図. カナダの輸出見通し
石炭輸出は漸増していく。

34

Canadian Demand Forecast
Canadian Coal Demand Forecast
60

60

60

59
56

55

55

million tonnes

50

47

47

40
30
20
10

Annual Coal Consumption

20
15

20
14

20
13

20
12

20
11

20
10

20
09

20
08

0

Used for Coal-Fired Electricity Generation

Canada’s Natural Resources – Now and for the Future

図. カナダ石炭需要推移（WVPU）：需要が減少するのは何故か？
（Stone）：オンタリオ州では石炭火力が禁止される。

Annex 1. Coal Mine Details

Canada’s Natural Resources – Now and for the Future

図. 炭鉱概要35

Annex 2. Coal-Fired Generation Plants

Canada’s Natural Resources – Now and for the Future

図.石炭火力発電

Speech 2 (Australia) 講演 2（豪州）
Coal Demand/Supply Outlook in Australia
豪州における石炭需給展望
Mr. John Karas, Manager, Clean Coal Technology Section,
Resources Division, Department of Resources, Energy and Tourism(DRET)
資源エネルギー観光省 資源部 CCT セクション マネージャー
ジョン・カラス氏
・

・
・

・
・

・

豪州石炭産業の概要を先ず説明する。豪州石炭産業は世界中の顧客にハードコール生産の 80％以上を輸出している。特にアジア太平洋区域においては原料炭生産の 80％、一般炭生産の 90％はアジア太平洋区域に輸出されている。
2008 年の金融危機は石炭市場に対しローラーコースターに乗ったような大きな影響を与えた。
2009 年は全体観として、ABARE（豪州資源農業経済局）の見通しでは、原料炭に関して、主要な輸入経済であった日本・韓国・EU が 23％減少させているのに反して、中国が前年比 286％増となる
2,700 万トンを輸入する。
世界の石炭市場の流動性は以下の数字を反映している。
2008/09 年度までの 3 年間では豪州石炭生産は 3.25 億トンから 3.30 億トンの範囲で安定していた。
新規供給能力投資があるものの、金融危機の影響や石炭需要の減少は生産能力以下の生産で落ちついている。
世界の原料炭と一般炭需要は特にアジアにおいて経済成長の影響を受けて、拡大すると見込まれる。ABARE は豪州石炭生産が 2009/10 年度に 3.46 億トンに回復、輸出量は 2.6 億トンから 2.7 億トンへ増加するが、輸出金額は 2008 年のピークから価格変動と豪ドル高の影響により減少すると予測している。大部分の石炭生産経済は豪州を含めて 2010 年には需要拡大するとの見方をしている。実際の対応は価格の変化や供給者間の競争力に依存する。個別経済における短期予測の困難性は為替変動により、更に増幅される。

36

2007/08
年度
327

2008/09年度
328

2009/10
年度
347（単位：百万ト

252

262

270

（億 AUD/

115
137
324/2.59

136
125
546/4.37140130294/2.35

石炭生産 （単位：百万ト
ン）
輸出
ン）
一般炭
原料炭
輸出額
兆円）

ABARE Estimates and Forecasts
・（Slide.5）原料炭輸入見通しは、ABARE による 2009-2014 年の主要輸入経済の原料炭需要の年平均変化率をしめす。世界全体の原料炭輸入量は 2.33 億トン。最大の需要増加経済はインドであり、国内原料炭資源に乏しく、製鉄需要が大きいためである。EU の伸びは石炭補助金の廃止と域内原料炭生産の減少による。中国の原料炭輸入は安定すると見込まれるが国内生産が計画通りに進まない
場合は輸入が増加する。

4. Metallurgical coal import growth(forecast annual average growth 2009-2014)
12

8

4

%

-4

2008 Imports
(Mt)

Japan

China

Taiwan

Korea

India

EU27

Brazil

World

54

7

6

24

25

52

12

233

Slide.5 原料炭輸入
・・（Slide.6）原料炭の輸出は豪州が新規炭鉱開発とインフラの改善により市場拡大に対応し 2008 年の1.35 億トンから 2009 年は減少するもののこの期間で年平均 3％の割合で増加し、現在に続いて低コ
ストの原料炭を輸出する。
カナダと米国は高コストのため輸出は減少する。ロシアは高い伸びを示すが、絶対量としては過去 5
年間に 500 万トンの増加に過ぎず、インフラへのアクセス問題がある。

37

5. Metallurgical coal export growth(forecast annual average growth 2009-2014)
4
3
2
1
%

-1
-2

2008 Exports(Mt)

Australia

CanadaUS

Russia

World

135

29

34

20

233

Slide.6 原料炭輸出
・（Slide.8）一般炭の輸入需要は基本的にアジア、特に中国とインドである。世界全体の輸入需要は
8.324 億トン。中国は安価な電力用として過度に石炭に依存しており、更に産業用と人口増加及び都市化の進行が拍車をかけているため、石炭需要は引き続き増加する。輸入は低廉な海上輸送運賃と国内の輸送インフラでの制約があり増加傾向にある。インドは 2017 年までの石炭火力発電を倍増させる政府方針である。政策的に発電容量 4GW の石炭火力を 9 基建設する計画であり、完成すれば長期間にわたり一般炭供給者にとりインドへの石炭供給の機会が得られる。インドでは同時に国内の低品位炭の混炭用として高品質炭の需要拡大がある。日本・韓国・EU においては炭素排出削減政策により成長は停滞する。

7. Thermal coal import growth(forecast annual average growth 2009-2014)
15

10

5

%

-5
2008
Imports (Mt)

Japan

Taiwan

Korea

India

EU27

China

World

135

62

73.5

34

193.9

34

832.4

Slide.8 一般炭輸入
・（Slide.9）世界的な一般炭需要にはインドネシア、豪州、コロンビア、南アフリカの生産拡大で対応している。インドネシアの安価な生産コストと生産能力により輸出は拡大していくが、国内需要の拡大に伴い次第に減少する。低硫黄・高品質炭に対する強い需要と安価な生産コストはコロンビアの成長を支える。南アフリカはインフラ制約が無くなれば輸出が増加する。豪州は新規炭鉱開発と輸出能力の開発計画が達成されれば中期的には増加する。中国は国内生産が国内消費に回る。米国は独立的

38

な石炭生産者であり、大西洋市場への伝統的な石炭輸出は減少する。

8. Thermal coal export growth(forecast annual average growth 2009-2014)
10

5

%

-5

-10
Australia China Indonesia South Colombia
Africa2008 Exports
126
(Mt)

42

198

66

68

US

Russia World

33

80

719

Slide.9 一般炭輸出・港湾インフラは多くのプロジェクトが進行中であるが、石炭需要が急増していた 2008/09 年度に進行したものであるが、着々と進行している。2014 年までには年間 9,000 万トンの取り扱い能力が増強されることを意味する。鉄道システムには多くのプロジェクトが提案・実施されている。

10. Port Infrastructure Expansion Plans
Port

・

・

Capacity as at 31 Dec
2008(Mtpa)

PlannedCapacity by 2014
(Mtpa)New South WalesPort Waratah Coal Services
Newcastle Coal Infrastructure GroupPort Kembla

102
18

113
30
18

Queensland
Abbot Point
Brisbane
Dalrymple Bay
Hay Point
Gladstone
Wiggins Island

21
5
68
44
75
-

50
8
85
44
75
25

Total

333

448

豪州は効率的で低価格の石炭供給経済である。豪州石炭産業は世界金融危機に生産調整とコスト削減で対応した。既にインフラ拡張計画は進捗しており、将来の石炭需要拡大に対応しており、長期的な国際石炭市場への主要石炭供給者たることを希望している。
国際的に豪州市場への参入意欲が中国・インドをはじめ大きい。豪州は中期的には国際石炭市場が成長することを確信している。

39

Speech 3 (Philippines) 講演 3（フィリピン）Coal Demand/Supply Outlook in the Philippines
フィリピンにおける石炭需給展望
Mr. Redentor Morelors, Senior Science Research Specialist,
Geothermal and Coal Resources Development Division,
Department of Energy (DOE)
エネルギー省 地熱石炭資源開発部 上級科学分析官 レデントー
ル・モーレロス氏
・

・
・
・

・
・

石炭の可採埋蔵量は 3.29 億トン。民間企業が採掘している亜瀝青炭の Semirara が最大で、1.28 億トンある。石炭の特徴は、年代的に若い 2,300～2,500 万年前の石炭で 2,555～6,666kcal/kg と幅広く賦存しているが、探査は進んでいない。

図．石炭資源分布
坑内採掘炭鉱も操業している。柱房採掘は幅 3ｍ-高さ 2ｍの坑道で展開している。長壁採炭は払面
長 50～100ｍ程度。選炭工場は 60tph 程度。
石炭採掘コントラクタは 46 社ある。全体生産は 3,977 千トン。最大の Semirara 炭鉱は年産 350 万トン
でシェアは 87％。
生産は 2000 年の 1,353 千トンから拡大中である。石炭輸入は 9,209 千トン、インドネシア炭が 8 割の7,348 千トン、中国炭 1,111 千トン、ベトナム炭 358 千トン、豪州炭 332 千トン。2000 年の石炭輸入は
6,814 千トンであり年ごとに増加している。
石炭消費は電力 8,769 千トン、セメント 3,063 千トンで全体消費は 12,235 千トン。
電力構成で石炭は 26％、天然ガス 32％に次ぐ電源である。現在建設中、計画段階の石炭火力は 10
件、2,760MW である。
2009 – 2014 COAL SUPPLY & DEMAND FORECAST(in MMMT @ 10,000 BTU/lb)
2012

2013

2014

DEMANDPower generation
Industry

12.83
10.74
2.09

2009

13.69
11.57
2.12

2010

14.00
11.86
2.14

2011

14.42
12.25
2.17

14.79
12.60
2.19

15.28
13.06
2.22

SUPPLY
Production
Importation

4.28
8.55

4.77
8.92

5.14
8.86

5.80
8.62

5.97
8.82

6.60
8.68

図.需給予測Source: 2007-2014 Phil. Energy Plan Update40(8) Featured Address I (Korea) 特別講演 1（韓国）Energy Policy for Climate Change 気候変動に関するエネルギー政策
Dr. Jin-Gyu Oh, Director, Department of Climate Change
Research, Korea Energy Economics Institute (KEEI)
韓国エネルギー経済研究院（KEEI）気候変動研究部門 部長
ジン・ギョ・オー博士

・韓国の数字は次のようである。
人口：4850 万人 経済：GDP$971 ビリオン、$20038/人 貿易$728 ビリオン
韓国の世界ランク エネルギー使用 10 位、油使用量 6 位、油輸入量 3 位、石炭と LNG 輸入 2 位、CO2 排出量 10 位
・2006 年の GHG 排出 84%・・・エネルギー部門 11%・・・産業部門
2%・・・農業 3%・・・廃棄物関連
CO2 増加 90 年～06 年で＋4.6％
エネルギー効率は上昇 GDP 当りのエネ消費は 2005 年 0.32→2006 年 0.31
・ 2030 年の予測
2020 年から人口減少の予測
2005 年～2030 年でｴﾈﾙｷﾞｰｲﾝﾃﾝｼﾃｨｰ（ｴﾈﾙｷﾞｰ消費/GDP）は 1.9％減・ 戦略☆ 低炭素社会を目指す ☆ｴﾈﾙｷﾞｰｾｷｭﾘﾃｨｰの増加 ☆温暖化対応→このためにＲ＆Ｄ、関連産業の育成、税制の見直しなどを行う。
2008 年～2012 年で第 4 回ﾍﾞｰｼｯｸﾌﾟﾗﾝを実行し、GDP あたりのエネ効率を 11.3％減
07→17 で－23.5％、07→30 で－44.8％とする。
・ 産業分野☆ 政府と企業間のパートナーシップ構築☆ 自動車は 800CC クラスの小型の税制優遇、ハイブリッドカー、自転車の推奨、公共交通へのシフト☆ 148 のビルの省エネ化☆ 家電は CO2 ラベリング
・ 電力部門☆ 2008年は石炭39％、原子力34％、LNG22％、重油2％→原子力の増加、石炭の減少をはかる
・ 再生エネ☆韓国はこの分野が少ない。今後大容量水力なども計画。
2015 年 4.3％→ 2020 年 6.1％→ 2030 年 11％☆ Feed in Tariff(FIT)の導入、発電量の 3％の RPS、100 万軒のグリーンホーム（太陽電池、ジオ
サーマル、木材ペレット、小容量風力）☆ オーシャン風力の開発、潮汐発電、バイオ、ソーラー（熱、電力）
2008 年 2.58％→2015 年 4.33％→2020 年 6.08％→2030 年 11.0％に拡大

41

Ｑ：韓国のグリーンエネルギー政策はうまくいくか？
Ａ：政府はエネルギーセクターと話し合いをしているが、政府の方針には強いものがあり、10 の政策を掲げて企業へも動機付けをしているところである。
Ｑ：韓国は原子力を増やすことにしているが、技術者不足などにより実行可能か？
Ａ：最近の設計はかなりスタンダード化しているので増加可能であると思う。

(9) Featured Address II (Korea) 特別講演 2（韓国）Obstacles and Path for Actual Implementation of CCT in Korea
韓国における CCT 遂行のための障害物と成功への道
Dr. Yongseung Yun, Head, Plant Engineering Specialist, Institutefor Advanced Engineering
先進技術研究所 プラント技術専門官 ヨンセン・ヨン博士

・ 韓国は 97％のエネルギーを輸入に頼っており、29～30％の電力は輸入燃料で賄われている。また、発電セクターで 38％の燃料を使用、28％の CO2 を排出している。韓国もクリーンコールテクノ
ロジーを導入してゆくことは重要である。
・ 韓国ではクリーンコールとして PFBC と IGCC について検討したが、PFBC の効率上昇には限度があるので、IGCC を選択した。IGCC は SHELL ベースの 300MW 機を 2013 年以降に建設する計画となった。
・ 検討の結果は例えばキャピタルコストは次のように評価された。
原子力：$5000/KW 以上
IGCC：$3000～5000/KW
通常石炭火力：$2000～4000/KW
コンバインドサイクル：$1000～1500/KW
・ IGCCは既設は稼働率に問題があると考えている。しかし建設から4～5年のトライアル＆エラーの時期を経てもまだ 90％程度の稼働率を確保できていない。今後稼働率の向上は期待できるのか？について検討された。
・ 一方、電力会社の立場としては発電価格競争下にあり、プルーブン技術採用に傾いている。また
天然ガスにも向かっており、IGCC の導入に消極的でもある。
また NGO からは化石燃料使用を減らすように言われている。
メーカーの技術も十分でなく、このように電力会社の決断がなかなか難しい状況である。
・ しかし IGCC（300MW）を建設するからには高稼働率、低コストが重要なファクターとなる。
・ 結論として、クリーンコールを推し進めるには政府のインセンテブが必須のであるが、IGCC に興味のある国々と興味をシェアし、韓国の IGCC を進めてゆかなければならないと考える。
Ｑ：PFBC と IGCC について比較検討したとの事であるが、日本などにはかなりの量の USC が実用されている。USC の評価はいかがか？
Ａ：日本等で USC が実用されていることは承知しており、USC についても評価している。しかし、202042

年と先を見るとこの時点では CCS が商用化し、義務付けられるかもしれない。CCS と組み合わせることを考えるとＵSC より IGCC の方が優れていると考え、IGCC を選択したものである。

(10) Session 5 セッション 5
Carbon Capture & Storage (CCS) R&D II CCS 研究動向 II
Session Chair (IEA)
Dr. Keith Burnard, Senior Energy
Technology Specialist, International Energy Agency (IEA)
セッション議長（IEA）IEA 上級エネルギー技術専門官
キース・バーナード博士

Speech 1 (Korea) 講演 1（韓国）Current Status CCS R&D in Korea
韓国における CCS 研究動向
Ms. Ga-Hye Yun, Researcher, Korea Institute of Energy
Technology Evaluation and Planning (KETEP)
韓国エネルギー技術評価機構（KETEP）研究員 ガ・ヒュエ・ヨン氏

・日本などと CO2 増加率を較べると、例えば 2006 年では日本は数％であるが韓国は 80％以上と高い数値である。そのために次の対応がなされている。
☆ エネルギー効率の向上 ☆CCS ☆資源技術 ☆GTL、CTL などのクリーンエネ
・ 電力も次のような方向を検討している。
☆クリーンコール技術：USC、IGCC など ☆電力輸送、配電技術☆発電システムの検討☆原子力の増加・CCS については Post、Oxy、Pre について検討されている。
☆ Post：化学吸収、ドライソルベント☆ Oxy：目標は 100ＭＷｅOxy をヨンドン発電所に適用☆ Pre：300ＭＷｅ IGCC を建設し 2013－14 年に運転に入る。CO2 貯留は朝鮮半島の東側、西側について検討している。
・ 韓国の CCS 国際的なＲ＆Ｄは、CSLF（Carbon Sequestration Leadership Forum）、IEA―GHG、APP、FutureGen などに参加している。
・ 結論として、韓国は CO2 分離コストについての大きな低下が必要であり、そのために新技術について研究している。現時点での分離コスト$45/t CO2 から$30/t CO2 以下に削減することが求められている。また韓国内の地下貯留容量が少ないことを認識し、それをどのように克服するかについても検討が必要である。
・ 注目されるＱ＆Ｄはなされなかった。

43

Speech 2 (US) 講演 2（米国）
Update on US DOE’s Sequestration Program
米国エネルギー省の地球化プログラム最新動向
Mr. Scott Smouse, Senior International Manager, US
Department of Energy (DOE), National Energy Technology
Laboratory (NETL)
エネルギー省 国立エネルギー技術研究所 上級国際部門マネージ
ャー スコット・スマウス氏代行

・CCS の目標は発生源で 90%以上の$45/t CO2 を分離し、99%の CO2 を永久貯留すること、CCS による発電単価の増加を IGCC の場合は 10%以下に抑え、Post および Oxy の場合には 35%以下に抑えることである。
・CCS の主要なチャレンジは新設/既設/IGCC に適用すること、コストがリーズナブルなこと、十分な貯留容量を準備すること、性能についても実用的なこと、などである。
・ このために USDOE は各種の Carbon Sequestration Program を立ち上げ、CCS のデモ試験並びに商用化について協力に支援している。
・ 2009 年の貯留プログラムは、約 39%のコストに対し企業支援すること、連邦政府は$631 ビリオンの投資をする。予算の内訳は次の通りである。
Regional Partnership60%
CO2 Use/Reuse
5%
CO2 Capture
14%
Simulation and Risk
Geologic Carbon Sequestration 5%
Assessment 6%
MVA
10%・Pre-Combustion CCS(IGCC)に対し、９プロジェクトに、$14.4Ｍのファンドをつけている。９プロジェクト
は次の 4 つのカテゴリーから選択されている。
☆ 高温高圧分離膜☆ 高効率吸収液☆ 固体ソルベント☆ その他
・ 特にＱ＆Ａは無し

44

Speech 3 (Australia) 講演 3（豪州）
Global Carbon Capture and Storage Institute ( GCCSI) Update
世界 CCS 研究所最新動向
Ms. Alice Gibson, CCS Project Manager, Global CCS Institute
世界 CCS 研究所 CCS プロジェクトマネージャー アリス・ギブソン
氏

・GCCSI の最新状況についての報告がなされた。組織、メンバーなどの紹介などで、特にＱ＆Ａもなされなかった。

(11) Final Thoughts on the Seminar – Japanese Policy for Cleaner Coal : Moving Towards Zero
Emissions2009 セミナー最終纏め‐ゼロエミッションを目指す日本のクリーナーコール政策
Mr. Hirotoshi Kunitomo, Director, Coal Division, Natural
Resources and Fuel Department, Agency for Natural
Resources and Energy (ANRE), Ministry of Economy, Tradeand Industry (METI)
経済産業省 資源エネルギー庁 資源・燃料部
石炭課長 國友 宏俊氏

1. 高効率石炭火力発電技術の開発動向
・石炭火力発電の革新的技術開発は CO2 削減において大変良い結果を生んでいる。
・日本において環境にやさしい石炭利用治術の開発は大変重要である。
・日本の石炭火力発電技術は、世界最高の高効率化を図っている。
・2050 年に向けての技術ロードマップを示す。
2. CCS の商業化・予定されている実証プロジェクト、またパイロット規模段階の CCS プロジェクト等を紹介する。
・CCS 実証プロジェクトを実行するために、2008 年 8 月に日本 CCS 調査㈱を発足させた。これは、29 の主要な日本企業から構成されている。
3. CCT への国際協力
・石炭火力発電技術と複合して推進している CCS プロジェクト（日豪；カライド、日米 CCS等）
・アジア各国と CCT について技術協力をしている（APP や APEC のようなマルチの取組や、2 カ国間のバイの取組等）

45

・CCT において、特に日本への主要な石炭供給国である豪州やインドネシアなどとは技術協力をしている
・石炭火力発電所のリノベーション化として、中国やインドと協力している
・Clean Coal for the Earth 計画として、日本から世界の国々へクリーンな石炭利用技術の普及促進を取り組んでいる。

(12) Closing Remarks

Mr. Scott Smouse, APEC EGCFE Chair
APEC EGCFE 議長 スコット・スマウス氏
Dr. Frank Mourits, APEC EGCFE Acting Chair
APEC EGCFE 議長代行 フランク・モーリツ博・この 2 日間のセミナーを通じて、APEC 各国だけでなくインドも加わって、世界的に石炭エネル
ギーに関して、石炭需給動向や CCT、CCS について議論ができたことは大変すばらしいことである。また、今回は APEC 各国（含、インド）だけではなく IEA からも参加を頂き、ゼロエミッシ
ョン社会に向けて活発な議論を行うことができた。ゼロエミッション社会に向けては、CCS 等の取組みがキーワードであるが、将来的にどのように取り組むべきなのか、議論を呼ぶところである。
・良い機会なので、APEC の中での我々EGCFE の取組みを紹介する。6 つの進行中のプロジェク
トがあり、2010～2011 年に向けての 3 件の新規進呈予定のプロジェクトがある。我々EGCFE は、
このような調査プロジェクトにも取組みつつ、本日のようなセミナーも開催している。このような活動は、セミナー期間中に開催されるビジネスミーティングで協議され、実行に移される。詳細は、APEC EGCFE の web site にて確認頂きたい。
・ここで再度、今回のセミナーを開催してくれた韓国政府知識経済省、KETEP、KIER、また、日
本政府、NEDO、JCOAL-JAPAC に感謝申し上げたい。また、インチョン地球博覧会事務局には、バンケットを用意してくれ、感謝申し上げる。また、講演者の皆さん、参加者の皆さん、他今回のセミナーに係ってくれた多くの方々に感謝申し上げ、セミナーを閉幕することとする。

46

３． テクニカルツアー概要

47

3. テクニカルツアー概要
実施日；平成 21 年 10 月 14 日（水）10:00～12:00
１．見学者 約 40 名
２．見学発電所 Yeongheung 火力発電所（オーナー；Korea South-East Power Co.）
３．発電所概要（１）構成
ユニット 1 号 800MW 超臨界圧ユニット
2号
3号

2,415t/h〃〃

870MW 超臨界圧ユニット

4号

255kg/cm2 569℃/566℃〃

2,673t/h〃〃

将来

5 号 870MW 超臨界圧ユニット

2,673t/h

将来

6号

〃

〃

255kg/cm2 569℃/566℃〃〃

255kg/cm2 569℃/566℃

〃

〃

〃

（ボイラは屋内式、煙突 200ｍ、排水処理設備、フライアッシュ回収設備設置）
注 1：5、6 号：2010 年～2014 年に建設予定
注 2：7、8 号の計画もあり（2017 年以降）
（２）燃料 石炭（豪州、インドネシア、カナダからの輸入炭）（３）環境設備

脱硝、EP、脱硫、低 NOx 燃焼（低 NOx バーナ、二段燃焼）（４）排出規制及び排出実績
項目

1，2

法律規制

45

55

20

仁川基準

70

70

30

実排出記録

26

40

6

法律規制

25

15

5

仁川基準

-

-

-

実排出記録

20

12

2

3，4

ＳＯｘ（ppm） ＮＯｘ（ppm）

煤塵（mg/sm3）

ユニット（５）その他・隣接地に下記を設置
太陽光発電（1MW、2006 年に建設）
海水小容量水力（3ＭＷ、2006～7 年に建設）
風力発電（20MW、2009～12 年に建設予定）
追設：海水小容量水力（5ＭＷ、2009～11 年に建設予定）

48

４．その他の主な説明（1）稼働率；95％。ベースロード運転（日中の稼働率；99％）。
韓国では原子力、石炭火力がベースロードで、天然ガスコンバインドが負荷調整運転となっている。
（2）プラント効率；41.7％（3）点検；2 年毎（4）環境設備の建設費；全体の 25％。環境設備の運転コストは全体の 4％。
（5）石炭の購入にあたっては、効率や環境基準が守られるような仕様で調達している。
５．現場視察セキュリティーと時間の制約から、発電所外観と石炭バースのみの見学となり、中央制御室の見学やボイラ室の見学は省略された。
・ ボイラは屋内式で、日本のように瀟洒なボイラ建屋が設けられている。
・ 貯炭場は屋外で、周囲に風よけの塀もなかったので、強風時には石炭粉が悲惨しそう。
・ 揚炭設備はスクリュータイプ、石炭コンベヤーはすべてカバーが設けられ、パイ
プコンベヤーも見えた。全体としては最新の設備となっている。
・ セキュリティーの問題から、発電所設備の写真撮影は禁止されている。
以

49

上

４．結果取纏め50

4. 結果取り纏め(1) 世界の石炭需給動向① 石炭の消費動向
先進諸国の景気低迷にも拘わらず、中国、インドでのエネルギー需要拡大により石炭生産
及び消費は拡大している。
2008 年の石炭消費量は 2007 年に比較して 6.1％増加して 67.67 億トン、石油換算量で33.37 億トン(toe)である。世界全体で石炭消費量は 2000 年から 2008 年の間に 46.0％増加している。
世界消費の 40.8％を占める中国が 2007 年比で 12.4％、2000 年比で+127％増加と引き続き急成長している。消費量で第 2 位の米国は 15.2％を占め、2007 年比で 0.1％の微減で、2000 年比では 6.2％の増である。第 3 位のインドは 8.6％を占め、2007 年比で 9.1％増加し、2000 年比では 60.4％増加している。この上位 3 ヶ国で世界の 64.6％を占めている。
中国とインドで石炭消費が急増しているが、BRIC’s に続いて経済成長が続くと見られる
VISTA（Vietnam・Indonesia・South Africa・Turkey・Argentina）諸国と ASEAN 諸国も経済成長により石炭への依存を高めており、大消費地域になりつつある。この他では中東地域や南米も将来的な消費拡大地域である。
2004 年から 2008 年の国別の石炭消費推移を図１～3 に示す。これらのグラフから明らかなように、これまでの石炭消費の伸びは、中国及びインドの石炭消費の伸びによるものである。
また、図 4 に米国 EIA による石炭消費予測を示す。この予測によれば、今後も中国の石炭消費の増大により、世界の石炭消費が増大していくものと思われる。

7,000,000

6,000,000

5,000,000

583,174

4,000,000
x1,000t

その他
ポーランド
南アフリカ
日本
ドイツ
ロシア
インド
アメリカ
中国

460,932
3,000,000

490,568

1,026,453

441,270
1,010,733

1,029,721

534,746

1,017,061

1,027,008

2,000,000

1,000,000

2,098,830

2,305,093

2,454,333

1,886,367

2004

2005

2006

2007

2,759,70802008

図１ 国別石炭消費推移（褐炭含む） （出典：IEA Coal Information 2009、作成：JCOAL）

51

6,000,000

5,000,000

その他
日本
南アフリカ
インド
アメリカ
中国

x1,000t

4,000,000

3,000,000
937,1122,000,000

1,000,000

913,152

932,692920,374

934,633

1,816,465

1,965,467

2,073,184

1,661,073

2004

2005

2006

2007

2,326,583

02008

図 2 国別一般炭消費推移 （出典：IEA Coal Information 2009、 作成：JCOAL）

900,000

800,000

700,000

600,000

x1,000t

その他
アメリカ
韓国
ウクライナ
ロシア
インド
日本
中国

500,000
57,36758,199400,000
57,67256,530300,000
60,884200,000

339,626

381,149

433,054282,365
100,000

225,294

0
2004

2005

2006

2007

2008

図 3 国別原料炭消費推移 （出典：IEA Coal Information 2009、 作成：JCOAL）

52

EIA 石炭消費予測

石炭消費量（百万トン）

10,000
9,000
8,000
7,000

米国
Japan
China
India
Total World

6,000
5,000
4,000
3,000
2,000
1,000
0
2006

2010

2015
2020
暦年

2025

2030

図 4 石炭消費予測 （単位：100 万トン） 出典：IEO2009/JCOAL 作成② 石炭の生産動向2008 年の世界の石炭生産量は 67.97 億トンで、2007 年実績の 63.98 億トンから 6.2％増加した。褐炭生産量 9.5 億トンを除いたハードコール生産では 58.45 億トンと 2007 年の 54.42
億トンから 7.4％増加した。
国別では、中国炭が 1985 年に米国炭を抜いて以来、世界最大である。主要な石炭生産
国は 2008 年における世界生産の 40.6％を占める中国を筆頭に、米国、インド、豪州、ロシア、
インドネシア、南アフリカ、ドイツ、ポーランド、カザフスタンである。生産上位の 3 ヶ国で64.1％を占めている。
生産方式は約 60％が坑内採掘であり、特に中国では 94％を占める。露天採掘の割合は豪州で 75％、米国で 69％である。
2009 年の生産速報では、OECD を中心とした世界的な景気後退と需要減少を受けて、米国は 9.80 億トンと前年比で-7.8％減産したが、中国では国内需要の着実な増加により 30.5
億トンと前年を 8.8％上回った。

53

7,0006,000

OthersCanadaVietnamMil. ｔ5,000

Indonesia
S.Africa

4,000

RussiaAustralia
India
USA

3,000
2,000

P.R.China

1,000

08

07

20

06

20

05

20

04

20

03

20

02

20

01

20

00

20

99

20

98

19

97

19

96

19

95

19

94

19

93

19

92

19

91

19

19

19

90

0

図 5 国別の石炭生産推移 （出典：IEA Coal Information 2009）(2) APEC 域の石炭生産及び消費動向(ア) 中国2008 年の一次エネルギー生産の 76.6%、消費の 68.6％が石炭であり、電力の 8 割は石炭火力である。エネルギー利用効率が低く、環境問題への対応を含め、省資源・省エネルギーの促進と自給率向上が図られている。
石炭生産は、2004 年の 19.6 億トンから、2008 年は 27.6 億トンへ 5 年間で 41％増加し、世界の 4 割を占める。中国統計局発表によれば 2009 年の石炭生産量は 30.5 億トンと前年比 8.8％の増加となった。
ちなみに、石炭埋蔵量は 1,145 億トンで、米国、ロシアに次ぎ世界第 3 位である。内訳は、
瀝青炭・無煙炭が 622 億トン(54.3%)、亜瀝青炭 337 億トン(29.4%)、褐炭 186 億トン(16.2%)である。
2009 年は石炭生産は拡大したものの、輸入が激増して輸入国に転じた。
表１ 中国の石炭生産及び消費の推移(単位:百万 t)
2000 年 2004 年 2005 年 2006 年 20072008
2009 年
年
年
生産量
1,231
1,956
2,159
2,320
2,549
2,761
3,049.9
消費量
1,215
1,886
2,099
2,305
2,543
2,760
3,020
輸出量
55.1
86.6
71.7
63.2
53.1
47.4
22.40
輸入量
2.2
18.6
26.2
38.1
51.0
45.6
125.83
輸出量－輸入
52.9
68.0
45.5
25.1
2.1
1.8 △103.43
量（出典： IEA Coal Information 2009/JCOAL Magazine）

54

石炭生産量・消費量（百万トン）

140

3,000

120

2,500

100

2,000

80

1,500

60

1,000

40

500

20

0

0
'00

'01

生産量

'02

'03

'04

'05

'06

'07 '08* '09*
輸入量

消費量

石炭輸入・輸出量（百万トン）

3,500

輸出量

図 6 中国の石炭需給動向 （出典：IEEJ）(イ) 米国
石炭は一次エネルギー消費の 24.3％を占め、石油・天然ガスに次ぐエネルギー源である。
2008 年の生産は、10.75 億トン、消費は 10.26 億トン（世界 2 位）である。その消費の 9 割にあたる
9.4 億トンが電力向けである。
石炭輸出はカナダ向け等 73.7 百万トン、輸入も 30.9 百万トンあり、現在は輸出が上回っているが、2028 年には輸入国に転じることも予想されている。
石炭生産・消費状況を、表 2 及び図 7 に示す。

生産量 (億ｔ)
消費量 (億ｔ)
電力消費(億ｔ)
輸出量(百万 t)
輸入量(百万 t)
輸出量－輸入量(百万 t)

2000 年
9.72
9.66
7.80
53.0
11.2
41.8

表 2 米国の石炭生産及び消費の推移
2005 年
2006 年
2007 年2008 年2009 年
10.39
10.68
10.53
10.63
9.78
10.30
10.17
10.27
10.18
9.05
9.41
9.31
9.49
9.45
8.47
45.1
45.0
53.7
74.0
53.6
27.5
32.9
33.0
31.0
20.5
17.6
12.2
20.5
42.8
30.1
（出典：EIA STEO 2010/ IEA）

55

2010 予測
9.155
9.335
8.719
56.4
37.8
18.6

石炭生産量・消費量（百万トン）

120

1,000

100

800

80

600

60

400

40

200

20

0

石炭輸入・輸出量（百万トン）

1,200

0
'00

'01

生産量

'02

'03

'04

消費量

'05

'06

'07

輸入量

'08*
輸出量

図 7 米国の石炭需給動向 （出典：IEEJ）(ウ) 豪州
一次エネルギー消費の 44％は石炭であり、発電電力の 76.1％は石炭火力である。2008 年の国内炭消費は 1.46 億トン、このうちの 86％、1.25 億トン(褐炭 0.64 億トン)が電力用である。これは我が国の電力用石炭消費量より多い。
生産は、2008 年 3.98 億トン、褐炭を除くと 3.25 億トンで世界 4 位の生産国である。生産の77.3％が輸出され石炭産業は基幹産業となっている。
可採埋蔵量も世界第 4 位となる 762 億トンである。内訳は、瀝青炭・無煙炭が 368 億トン(48.4%)、
亜瀝青炭 21 億トン(2.7%)、褐炭 373 億トン(48.8%)である。
販売炭埋蔵量は、原料炭 45.2 億トン、一般炭 79.2 億トンで 124.3 億トンとされている。
表 3 豪州の石炭生産及び消費の推移

生産量
原料炭
一般炭
褐炭
消費量
輸出量
原料炭
一般炭

2000 年
306.7
103.8
135.7
67.3
128.1
187.0
99.2
87.8

2004 年
2005 年
2006 年
352.2
367.3
367.5
116.9
128.3
124.0
168.9
171.9
175.7
66.3
67.2
67.7
131.3
140.0
141.3
218.4
231.3
231.3
110.8
123.9
119.3
107.6
107.4
112.0
（出典： IEA Coal Information 2009）

56(単位：百万トン）
2007 年2008 年
389.4
397.8
141.8
140.0
181.9
185.3
65.6
72.4
138.4
145.6
243.6
252.2
131.2
136.9
112.4
115.3

(エ) タイ
タイにおける電力需要は、図 8 に示したように今後大幅に伸びることが予想されている。そのよ
うな状況において、タイ政府は今後の電力需要を賄うために、天然ガスと輸入石炭への依存度を高めていく計画である。

図 8 タイにおける燃料毎の電力供給計画

図 9 タイにおける石炭需要予測

57図 9 にタイにおける今後の石炭需要予測を示した。2008 年は 3,480 万トンであったが、電力及び一般産業とも石炭需要が伸びると予測されており、2021 年には 4,800 万トンに達する見込みである。
(オ) インド
インドは APEC 加盟国ではないが、世界における石炭消費の割合が大きい国であるので、APEC 石炭セミナーに招へいし情報交換を行っている。以下にインドの石炭状況を示す。
図 10 に示したように、2008 年の石炭生産量は約 5 億トンで、輸入炭が約 6 千万トンである。

図 10 インドの炭田と石炭資源量、生産量及び輸入量58

表 4 インドの石炭需要予測

表 5 インドにおける石炭生産予測

表 4 には、セクター別の石炭需要の実績及び予測を示した。2011 年には 7 億トンを超すと予測されている。
表５には、石炭生産実績と今後の予測を示した。

59

(3) アジア地域における石炭消費及び生産予測
2030 年までのアジア地域における石炭消費予測を図 11 及び表 6 に示した。この予測は、IEAによる予測データをもとに作成しているが、今後 2030 年までに 13.66 億トン増加すると予測されており、そのほとんどが中国とインドである。

6,000
926

Increase of Consumption(2008-2030)

5,000
357

-41
3,000

1366Mt

125

4,000

Other
Asia

-1

China India Japan Korea Others

Korea
Japan

2,000

India
1,000
China
0

1980

1990

2000

2008

2010

2020

2030

図 11 アジア地域における石炭消費予測（出典：(財)石炭エネルギーセンター）
表 6 アジア地域における石炭消費予測（出典：(財)石炭エネルギーセンター）

Coal Consumption in Asia
(Million tonnes)

China
India
Japan
Korea
Others
Total

ActualForecast
Average Annual Growth Rate (%)
1980 2008 2010 2020 2030 08/80 10/08 20/10 30/20 30/07
626.0 2468.8 2497.8 2888.9 3394.4
5.0
0.7
1.5
1.6
1.4
108.6 494.4 483.2 549.4 851.6
5.6
-1.3
1.3
4.5
2.3
87.7 184.0 178.1 153.7 143.4
2.7
-1.8
-1.5
-0.7
-1.1
27.8
92.0
91.9
91.6
91.3
4.4
0.0
0.0
0.0
0.0
48.0 194.8 190.6 210.4 319.3
5.1
-1.2
1.0
4.3
2.1
898.2 3434.1 3441.5 3893.9 4800.1
4.9
0.1
1.2
2.1
1.5

図 12 及び表 7 に、アジア地域における石炭生産予測を示した。このデータも IEA による予測データを基に作成しているが、今後 2030 年までに 12.64 億トン増加すると予測されており、そのほとんどは中国、インド、インドネシアが占めている。

60

5,000
Increase of Consumption

2320

4,500

(2008-2030)

4,000

1264Mt

3,500

186

167

42

3,000
China

India Indonesia Others

2,500

Others2,000

Indonesi

1,500

India

1,000

China
500
0

1980

1990

2000

2008 2010

2015

2020

2030

図 12 アジア地域における石炭生産予測(出典：（財）石炭エネルギーセンター)

表 7 アジア地域における石炭生産予測(出典：（財）石炭エネルギーセンター)

Coal Production in Asia

China
India
Indonesia
Others
Total

Actual1980
2008
620.2 2479.7
111.0
439.5
0.3
236.2
80.9
83.0
812.4 3238.4

Forecast
2010
2020
2506.6 2807.1
411.1
426.4
248.4
316.1
86.9
105.5
3256.6 3655.0

2030
3336.0
640.0
397.0
123.0
4496.061(Million tonnes)
Average Annual Growth Rate (%)
07/80 10/08 20/10 30/20 30/07
5.2
0.5
1.1
1.7
1.3
5.4
-3.3
0.4
4.1
1.5
27.8
2.6
2.4
2.3
2.4
0.0
2.3
1.9
1.6
1.8
5.2
0.3
1.2
2.1
1.4

(4) 石炭の輸出入
図 14 に 2008 年の世界の石炭輸出量及び輸入量を示した。豪州から多くの石炭がアジア地域に輸出されており、またインドネシアから日本、中国、インド、その他のアジア地域に輸出されている。

22.6Mt

その他欧州
Other Europe
37.7Mt11.8Mtポーランド
Poland
11.8Mt18.8Mtカザフスタン
Kazakhstan
22.6Mtロシア
Russia100.2Mt

OECD欧州OECD Europe 62.7Mt
257.9Mt

カナダ
Canada30.4Mt

11.2
Mt
11.3Mt中国
China
53.7.Mt
8.2Mt

16.4Mt30.5Mt51.6Mt北米
N. America
48.7Mt日本
Japan
182.3Mt

35.9Mt3.3Mt
114.8Mt

3.2Mt

7.6Mt
8.8Mt

OECD欧州OECD Europe
257.9Mt
米国
United States
19.0Mt
53.4Mt25.5Mt4.7Mt

136.6Mt
77.6Mt

9.4Mt

南アフリカ
South Africa
66.7Mt13.0Mtその他アジアOther Asia
29.7Mt270.1Mt

アフリカ・中東
Africa & Mid. East
21.5Mt
9.8Mt

5.7Mt

その他欧州
Other Europe
37.7Mt29.5Mtコロンビア 5.7Mt
Colombia
67.2MtインドネシアIndonesia
202.2Mt

6.7Mt
豪州
Australia
243.6Mt

4.9Mt

南米
Latin America
23.3Mt

図 14 世界の石炭輸出量及び輸入量(2008)
豪州からの石炭輸出は、輸出量が増加するにつれて港湾設備が不足し、輸出がタイト化しているが、表 9 に示すような港湾設備容量の拡張計画が示された。ニューサウスウェー
ルズ州では Newcastle における拡張計画、クイーンズランド州では、Abbot Point、
Brisbane、Dalrymple Bay、Wiggins Island における拡張計画が示された。

62

表 9 豪州における石炭輸出港拡張計画

また、豪州 John Karas 氏のプレゼンテーションにおいて、世界の原料炭及び一般炭の2009 年から 2014 年における輸出量及び輸入量の伸び率の予測が示されたので、図 15 から図 18 に紹介する。
図 15 に示したように、原料炭の年間輸入量伸び率の予測の最も大きい国はインドである。中国はグラフが示されていないが、今後輸入原料炭が増えることも考えられる。日本、及び韓国は減少すると予測されている。

図 15 原料炭の年間輸入量伸び率の予測（2009－2014）
図 16 に原料炭の年間輸出量伸び率の予測を示した。今後原料炭の輸出量が増加するの

63

は、豪州及びロシアで、カナダと米国は減少すると予想されている。

図 16 原料炭の年間輸出量伸び率の予測（2009－2014）
図 17 には一般炭の年間輸入量伸び率の予測を示したが、今後大きく増加するのは中国とインドであると予測されている。台湾及び韓国も増加傾向にあるが、日本はわずかに減少すると予測されておる。

図 17 一般炭の年間輸入量伸び率の予測（2009－2014）64

図 18 に一般炭の年間輸出量伸び率の予測を示したが、今後一般炭の輸出が伸びるのは、
豪州、インドネシア、南アフリカ及びコロンビアと予測されている。一方、中国及び米国は減少すると予測されている。

図 18 一般炭の年間輸出量伸び率の予測（2009－2014）
図 13 及び表 8 に、IEA の予測をベースにしたアジア地域における石炭需給予測を示したが、今後アジア地域では、石炭消費量が石炭生産量を上回ることが予測される。今後は豪州をはじめ、南アフリカ、ロシア等からの輸入が考えられるが、石炭需給がタイト化すると考えられる。

6000
Production

Consumption

5000
4000
3000
2000
1000
0
1980

1990

2000

2010

2020

2030

図 13 アジア地域における石炭需給予測(出典：（財）石炭エネルギーセンター)65

表 8 アジア地域における石炭需給予測(出典：（財）石炭エネルギーセンター)

Coal Supply and Demand in Asia
(Million tonnes)

Production
Consumption
Gap

Forecast
ActualAverage Annual Growth Rate (%)
1980 2008 2010 2020 2030 08/80 10/08 20/10 30/20 30/07
812.4 3238.4 3256.6 3655.0 4496.0
5.2
0.3
1.2
2.1
1.4
898.2 3434.1 3441.5 3893.9 4800.1
4.9
0.1
1.2
2.1
1.5
85.8 195.7 184.9 238.9 304.1
3.0% -2.8% 2.6% 2.4% 2.0%

(5) APEC 地域における CCT 開発動向
① インドネシア

インドネシアは褐炭の埋蔵量が多いことから、褐炭を利用する技術開発が活発に行われている。
UBC(Upgrading Brown Coal)の技術開発の実証試験が、日本とインドネシアの協力において実施されているが、そのほかにも図 14 に示したように、褐炭を使った CWM(Coal Water
Mixture)の技術開発のほか、褐炭ガス化によるアンモニア及び肥料の製造技術の開発や、褐炭の液化技術の開発が実施されている。
インドネシアでは図 15 に示したように、エネルギー政策の一環として、これまでほとんど使われていない褐炭を利用する技術開発に力を入れている。

図 14 褐炭を利用した CWM(Coal Water Mixture)の製造技術フロー66

図 15 インドネシアにおけるエネルギー政策を支援する CCT の開発コンセプト③ 国
中国では、石炭燃焼技術、石炭ガス化技術及び石炭液化技術全てにわたって活発な技術開発が進められている。石炭燃焼技術では、日本をはじめとする海外からの技術導入により、世界最先端の USC(超々臨界圧)のボイラ技術が導入されているとともに、大型流動床燃焼技術についても、海外技術を導入し 600MW 級の FBC ボイラが建設されている。
石炭ガス化技術については、中国独自の技術開発による石炭ガス化炉を使った 250MWの IGCC プラントが建設されているとともに、石炭ガス化炉については海外の Shell、GE 及びSiemens の技術導入と中国華東理工大学により開発された OMB ガス化炉の導入により、石炭ガス化によるアンモニア、尿素肥料及びメタノール製造等が既に商業化されている。
また、石炭液化技術では、石炭直接液化については、神華集団公司が商業プラントを建設し、現在運転が行われており、また間接液化については神華集団公司をはじめいくつかの企業がパイロット規模の開発を進めているところである。
今回の会議では、図 16 に示したプラズマを使った石炭バーナの開発について発表があったので紹介する。この技術は、石炭バーナ部分にプラズマを使うことにより NOｘの発生を低減する技術であるが、プラズマの発生装置のコストと NOｘがどこまで低減できるか等が今後の課題である。

67

図 16

プラズマを使った低 NOｘバーナの開発③韓国
韓国では、2006～2014 年において 300MW の IGCC 実証プラント試験が計画されている。
世界の４大実証プラント及び日本の勿来 IGCC プラントに続いて、韓国及び中国が同クラスの実証試験を計画していることになる。

図 17 韓国における IGCC 開発計画

68

図 18 世界の IGCC 実証プラントと韓国の実証試験実施場所

図 19 世界で運転中の IGCC プラント

(6) APEC 地域における CCS 関連技術開発の現状
今回の会議で発表された APEC 地域における CCS 関連技術開発の現状を紹介する。
韓国では、2013～2018 年において既設の無煙炭焚 125MW のボイラを酸素燃焼に改造
して、リパワリングするとともに、CO2 回収試験を実施する計画である。

69

図 20

酸素燃焼に改造する予定の既設ボイラの仕様

図 21 酸素燃焼実証プロジェクトの実施計画

70

次に、カナダにおける CCS 関連プロジェクトの概要及び場所を図 22 に示した。カナダでは、
CO2 を貯留する場所として、EOR の場合と帯水層の場合の両方を計画している。

図 22 カナダにおける CCS 実証プロジェクト計画
中国からの発表では、図 23 に示すように中国における CO2 貯留のポテンシャル地域について示された。

71

(7) まとめ・今後 APEC 地域における石炭消費量は、中国、インドを中心に大幅に増加することが予測される。それに伴って、豪州、インドネシアの石炭輸出量が増加するとともに、新しくロシア、
南アフリカ、コロンビアの石炭輸出量が増加すると考えられる。
・CCT の開発及び導入に関しては、中国が最も活発であるが、インド、韓国及びインドネシアも活発に進めている。
・CCS については、米国及びカナダで実証試験が幾つも計画されている。今後、中国、韓国、
日本も実証試験を実施する計画である。
以上

72

資料集

１． セミナープログラム

資料1

Cleaner Coal: Moving Towards Zero Emissions
2009 APEC Clean Fossil Energy Technical and Policy Seminar
October 12-14, 2009
Songdo Convensia, Incheon, Korea

Organized under the direction of the
APEC Expert Group on Clean Fossil Energy (EGCFE)

Steering Committee
Japan: Ministry of Economy, Trade and Industry (METI)
Korea: Ministry of Knowledge Economy (MKE)
USA: Department of Energy (DOE)

Supported and Sponsored by
Japan: New Energy and Industrial Technology Development Organization (NEDO)
Japan Coal Energy Center-Japanese Center for Asia Pacific Coal Flow (JCOAL-JAPAC)
Korea: Korea Institute of Energy Technology Evaluation & Planning (KETEP)
Incheon Global Fair & Festival Organizing Committee (IGFFOC)
Korea Institute of Energy Research (KIER)
USA: Department of Energy (DOE) National Energy Technology Laboratory (NETL)

資料2

October 12, 2009 (Monday)
Room No: Premier Ballroom A (2F)

08:30-9:00

Registration

09:00-09:55

Opening Session
Chair: (Korea) Prof. Hee Chan Cho, Seoul National University
Opening Address 1
Mr. Scott Smouse, APEC EGCFE Chair
Opening Address 2(Korea) Dr. Joon-Hyun Lee, President, Korea Institute of Energy Technology Evalution and Planning (KETEP)
Opening Address 3(Korea) Mr. Kab-Won Oh, Senior Vice Chairman of Global Fair & Festival, Incheon
Keynote Address(Japan) Mr. Yoshihiko Nakagaki, Chairman, JCOAL & Corporate Adviser, J-Power
Keynote Address(Korea) Dr. Jong Nam Kim, Director of Climate Change Technology Research Division, Korea Insititute of Energy
Research (KIER)

09:00-09:05
09:05-09:10
09:10-09:15
09:15-09:35
09:35-09:55

09:55-10:15

Coffee Break

10:15-12:15

11:55-12:15

Session 1: Coal Demand/Supply Outlook in APEC Region (i) – Environmental Friendly Coal Policy (i)Chair: (Canada) Dr. Frank Mourits, Senior Climate Advisor, Natual Resources Canada (NRCan)
Speech 1 Coal Demand/Supply Outlook in China(China) Mr. Chen Qi, Director-General, Industry Coordination Department, China National Coal Association(CNCA)
Coal Demand/Supply Outlook in India(India) Mr. K.S. Kropha, Joint Secretary, Ministry of Coal (MOC)
Coal Demand/Supply Outlook in Korea(Korea) Mr. Jae Hyeok Jang, Deputy General Manager, Korea East-West Power Co
Coal Demand/Supply Outlook in Indonesia(Indonesia) Mr. Mangantar S. Marpaung, Directorate of Mineral, Coal & Geothermal Technics andEnvironment, Ministry of Energy and Mineral Resources (MEMR)
Coal Policy in Japan(Japan) Mr. Yoshitaka Watabe, Director for Coal Policy, Director-General’s Secretariat, Agency for Natural
Resources and Energy (ANRE), Ministry of Economy, Trade and Industry (METI)
Q&A

12:15-13:30

Lunch

10:15-10:35
10:35-10:55
10:55-11:15
11:15-11:35
11:35-11:55

Room No: 113(1F)

Room No: 114(1F)

15:10-15:30

Session 2-A: Advanced Clean Coal Technologies I
Chair: (USA) Dr. Chao Chen, Manager, Power
Select, Maison WorleyParsons
Development of the Circulating Fluidized Bed for
the Energy Technology in Korea(Korea) Dr. Dowon Shun, Principal Researcher, Korea
Institute of Energy Research (KIER)
R&D on Coal Water Mixtures as Preparation of a
CWM Demonstration Plant in Indonesia(Indonesia) Dr. Datin Fatia Umar, Dr. Bukin Daulay and
Mr. Chiaki Suyama, tekMIRA
Role of Advanced Coal Cleaning Technologies inGreenhouse Gas Reduction(USA) Dr. Roe-Hoan Yoon, Director, Center for
Advanced Separation Technologies, Virgina
Polytechnic University
R&D on Clean Coal Technology in Indonesia(Indonesia) Dr. Bukin Daulay, Head, Agency of R&D for
Energy and MineralResources, R&D Centre for Mineraland Coal Technology (tekMIRA), Ministry of Energy andMineral Resources
Plasma Ignition Technology for New and Retrofit
Pulverized-Coal Power Plants(China) Mr. Zhang Yonghe, Manager, Beijng Branch,
Yantai Longyuan Power Techonology Co.,Ltd., and Ms.
Zhao Xin, Deputy Manager, Securities Dept., GuodianTechnology & Environment Group Co., Ltd.
Q&A

15:30-15:50

Coffee Break

13:30-15:30

13:30-13:50

13:50-14:10

14:10-14:30

14:30-14:50

14:50-15:10

資料3

Session 2-B: Carbon Capture & Storage (CCS) R&D I
Chair: (Korea) Dr. Byoung Moo Min, Principal
Researcher, Korea Institute of Energy Research (KIER)
International Energy Agency Perspective on CCS(IEA) Dr. Keith Burnard, Senior Energy Technology
Specialist, International Energy Agency (IEA)
Guidelines for CCS-Ready Power Plants in APEC
Developing Economies (APEC Project Report)(Australia) Dr. Amir Tadros, Project Manager, Energy
Systems, Aurecon
CCS Policy and Development Status in Japan(Japan) Dr. Masato Takagi, Director, Tokyo Branch,Research Institute of Innovative Technology for the Earth(RITE)
Weyburn-Midale CCS Project Update(Canada) Dr. Frank Mourits, Senior Climate Advisor, Natual
Resources Canada (NRCan)

Status of Oxy-fuel Combustion Project in Korea(Korea) Dr. Sung Chul Kim, Leader of Oxy-fuel Combustion
Project, Korea Electric Power Research Institute (KEPRI)

Q&A15:50-17:50

Session 3-A: Advanced Clean Coal Technologies II
Chair: (USA) Dr. Roe-Hoan Yoon, Director, Center
for Advanced Separation Technologies, Virgina
Polytechnic University

15:50-16:10

NEDO's Activities for Clean Coal Technology(Japan) Mr. Manabu Hirata, Project Coordinator,
Environment Techonology Development Dept.,, NEDO

16:10-16:30

16:30-16:50

KIER CTL Project’s Status and Prospect(Korea) Dr. Heon Jung, Center Leader, Clean Fossil
Energy Research Center, Korea Institute of Energy
Research (KIER)
EcoNomics - A Systematic Analysis Methodology
and Tool for Fossil Fuel Power and CCS ProjectEvaluation(China/USA) Dr. Chao Chen, Manager, Power Select,
Maison WorleyParsons

16:50-17:10

Development Status of IGCC in Korea(Korea) Dr. Dal Hong Ahn, Leader of IGCC Project,
Korea Electric Power Research Insitute (KEPRI)

17:10-17:30

Australian CCT and CCS Developments(Australia) John Karas, Manager, Clean Coal
Technology Section, Resources Division, Departmentof Resources, Energy and Tourism (DRET)

17:30-17:50

Q&A

17:50

Day 1 Adjourns

Session 3-B: Coal Demand/Supply Outlook in APEC
Region (iii) – Environmental Friendly Coal Policy (iii)
Chair: (Korea) Prof. Hyung Taek Kim, Ajou University
Coal Demand/Supply Outlook in the World(Japan) Dr. Shigeki Sakurai, Senior Executive Director,
Japan Coal Energy Center (JCOAL)
Coal Demand/Supply Outlook in Thailand(Thailand) Mr. Viroj Sivavong, Chief, Coal Management
Department, Electricity Generating Authority of Thailand(EGAT)
Coal Demand/Supply Outlook in United States(USA) Dr. William Watson, Coal Team Leader, Energy
Information Administration (EIA), Department of Energy(DOE)
Coal Demand/Supply Outlook in Malaysia(Malaysia) En Ahmad Johari Jaffar, Head of Market
Operations Unit, Electricity Supply Regulatory
Department, Energy Commission, Ministry of Energy,
Green Techonology and Water (KettHA)

Q&A

18:30-20:30 Dinner Reception (Hosted by Incheon Global Fair & Festival)

資料4

Room No: Premier Ballroom B

October 13, 2009 (Tuesday)
Room No: Premier Ballroom A (2F)
08:30-09:00 Registration
09:00-10:40 Session 4: Coal Demand/Supply Outlook in APEC Region (ii) – Environmental Friendly Coal Policy (ii)
Chair: (USA) Dr. William Watson, Coal Team Leader, Energy Information Administration (EIA), DOE
09:00-09:20 Coal Demand/Supply Outlook in Canada(Canada) Mr. Kevin Stone, Senior Commodity Analyst, Minerals and Metals Sector, Natural Resources Canada(NRCan)
09:20-09:40 Coal Demand/Supply Outlook in Vietnam(Vietnam) Dr. Kieu Kim Truc, Deputy General Manager, Division of Science, Technolog and Development Strategy,
VINACOMIN Group
09:40-10:00 Coal Demand/Supply Outlook in Australia(Australia) Mr. John Karas, Manager, Clean Coal Technology Section, Resources Division, Department of
Resources Energy and Tourism (DRET)
10:00-10:20 Coal Demand/Supply Outlook in the Philippines(Philippines) Mr. Redentor Morelors, Senior Science Research Specialist, Geothermal and Coal Resources
Development Division, Department of Energy (DOE)
10:20-10:40 Q&A
10:40-11:00 Coffee Break
11:00-11:30 Featured Address I: Energy Policy for Climate Change(Korea) Dr. Jin-Gyu Oh, Director, Department of Climate Change Research, Korea Energy Economics Institute(KEEI)
11:30-12:00 Featured Address II: Obstacles and Path for Actual Implementation of CCT in Korea(Korea) Dr. Yongseung Yun, Head, Plant Engineering Center, Institute for Advanced Engineering
12:00-13:30 Lunch
13:30-15:10 Session 5: Carbon Capture & Storage (CCS) R&D II
Chair: (IEA) Dr. Keith Burnard, Senior Energy Technology Specialist, International Energy Agency
13:30-13:50 Current Status CCS R&D in Korea(Korea) Ms. Ga-Hye Yun, Researcher, Korea Institute of Energy Technology Evalution and Planning (KETEP)
13:50-14:10 Update on USDOE’s Sequestration Program(USA) Mr. Scott Smouse, Senior International Manager, U.S. Department of Energy, National Energy Technology Laboratory (USDOE/NETL)
14:10-14:30 Global Carbon Capture and Storage Institute (GCCSI) Update(Australia) Ms. Alice Gibson, CCS Projects Manager, Global CCS Institute14:30-14:50 Q&A
14:50~15:10 Final Thoughts on the Seminar: Japanese Policy for Cleaner Coal: Moving Towards Zero Emissions(Japan) Mr. Hirotoshi Kunitomo, Director, Coal Division, Natural Resources and Fuel Department, Agency for
Natual Resources and Energy (ANRE), Ministry of Economy, Trade, and Industry (METI)
15:10-15:20 Closing Remarks: Mr. Scott Smouse, APEC EGCFE Chair
15:20

Day 2 Adjourns
Room No: Premier Ballroom B (2F)

16:00-19:00 APEC EGCFE Business Meeting (Official Representatives Only)

October 14, 2009 (Wednesday)
TECHNICAL TOUR
9:00 ~ 12:00
Yeongheung Thermal Power Plant

資料5

Room No: 301 (3F)

２． 講演資料

資料6

(1) 開会セッション

資料7

APEC Seminar Opening Address
Thank you for the kind introduction.
Dr. Joon-Hyun Lee, President, Korea Institute of Energy Technology Evaluation and
Planning, Korea
Mr. Scott Smouse, Chair, APEC Expert Group on Clean Fossil Energy, International
Coordination Team Leader, National Energy Technology Laboratory, Department ofEnergy, United States of America,
Distinguished guests, ladies and gentleman,

I'm Yoshihiko Nakagaki from Electric Power Development Co., Ltd., currently
serving as the Chairman of the Japan Coal Energy Center. I am very much honored to
be presented with this opportunity to make the keynote address at this APEC seminar.
Looking back at the recent status of the economy and the energy environment, theglobal economy, including the developed and developing countries, was affected by theworst recession since World War II, which resulted from the global financial crisis
typified by the collapse of Lehman Brothers in the US in September 2008. Currently,
the global economy is gradually getting back on track to recovery, driven by the
emerging economies such as China; however, the recession lead to rapid fall in energy
demand, and the energy prices including for fossil fuel that had rallied along with theeffect from the financial bubble experienced a sharp collapse. The global energy market
is certainly in a very vulnerable situation.
Although the energy situation is expected to remain uncertain and unstable for sometime, the demand for energy shall certainly increase in the mid to long term based on thestrong economic growth in the emerging and developing countries such as China andIndia, and the energy market price is likely to start rising again. Therefore, securing
stable energy supply should become an increasingly important issue for the countries
around the world.
On the other hand, global warming, an issue that was raised during the latter half of

資料8

the 20th century, continues to evolve, and has become the largest political issue of thiscentury. At the 15th COP meeting to be held in Copenhagen in December 2009,
discussions will be held with respect to the international framework concerning thegreenhouse gas reduction target for the post-Kyoto Protocol era, between 2013 and2020. However, looking at each country’s approach, there are significant gaps incommitments even among developed countries such as the EU, US and Japan; and huge
gaps between the developed countries and emerging or developing countries indicate
the difficult road that lies ahead for reaching an agreement.
In Japan, the Democratic Party of Japan came into power in September, and Prime
Minister Hatoyama expressed Japan's intention to take the lead in tackling climatechange by announcing a mid term target of 25% reduction in greenhouse gas emissions
by 2020 compared with 1990 levels at the UN Climate Change Summit held on
September 22.
However, achieving this goal is not an easy task economically or
technologically, as Japan already has highly advanced energy conservation measures inplace. In fact, many stakeholders in Japan have been voicing their opinions thatappropriate proposals based on sufficient and practical discussions should be prepared
before the international negotiations to be held around the climate conference COP 15.
The coal industry must also pay utmost attention to this issue.
Let us now turn to coal. Various countries and professionals acknowledge that coal is,
and will continue to be, utilized as the core resource supporting the global energy supply,
as it is the most abundant and economically stable fossil fuel. There are some simplistic
arguments that the use of coal should be restricted in order to resolve the global
warming issue; however, this is a typical shortsighted argument that is detrimental toenergy security.
In June, the Ministry of Economy, Trade and Industry published a report by the“Clean Coal Panel,” openly addressing its basic approach towards future usage of coal.
This was a landmark and timely report in that it clearly described the strategies androles to be adopted by Japan in aiming to achieve coexistence between the global
environment and coal usage without conflict. There were three key messages in thereport:Firstly, the basis of Japanese energy policy lies with balanced and simultaneousachievement of the “3Es,” i.e., Economy, Energy Security and Environment. For thispurpose, coal will continue to play a role into the future, and further efforts towards

資料9

clean coal technology will be essential.
Secondly, with respect to environmental issues concerning coal, Japan hascommercialized the most efficient coal-based plants including coal-fired power plants,
and is able to offer immediate and significant contributions to the achievement of the3Es on global basis, by making Japanese coal technologies available to other countries.
Thirdly, as a long term goal, Japan shall apply the best practices gained throughcoal-fired power and other technologies to promote integrated development ofinnovative efficient coal utilization technologies and carbon capture and storage (CCS)
technologies that seek to minimize carbon emissions and deploy the results overseas as
the first runner.
The panel also proposed “COOL GEN Plan” and “Clean Coal for Earth Plan,” twoinitiatives for comprehensive promotion of these ideas.
With the progress of the global warming and instability in the energy markets, there is
growing uncertainty over the energy policies. Our role is to provide accurate
information and opinions to various governments and international organizations. In
addition, while acknowledging the uncertainties that lie ahead, we must prepare rational
and practical measures towards achievement of stable energy supply and environmental
conservation based on development and utilization of clean coal technologies. The
potentials of Asia-Pacific countries will be the largest driving force for achieving
sustainable growth of global economy in the 21 st century, and needless to say, coal willbe the key energy resource supporting this.
In this APEC seminar, the current status of coal use and projects for further
development of clean coal technology centering on efficient use and CCS will bereported over the two days. I hope this seminar will be a fruitful one through active
discussions by everyone. Thank you for your kind attention.

資料10

13

CO2 Capture and Storage (CCS)
CaptureSupercritical CO2
110 barPower plant, Iron & Steel,
Cement, Petrochemical Ind.
1,000MW, 20,000 t-CO2/day

Transport

Storage

Saline aquifers,
Enhanced Oil Recovery

We have to develop the cheapest CO2 capture
process資料11
producing supercritical CO2.

Compression Energy for CCS
Pin

Pout

Pin → P(liquefaction) → P (s.c. 110 bar)
72 bar at 30oC

Compression energy of CO2

資料12

14

15

2.1 Absorption by aqueous ammonia(NH4)2CO3 (aq) + CO2 (g) + H2O ↔

2NH4HCO3 (aq)Feed: 100 Nm3/hcoal power plant flue gas
Absorption: 25oC,
Regeneration: 80oC~120oC
Product > 99.9 vol% CO2
Recovery : 90 %Energy consumption < 800 kcal/kg CO2
Pressure of product CO2 > 6.5 bar
Future plan:
2,000 Nm3/h pilot plant by 2012
Ambient pressure regeneration(Regen. T: 80oC)

80

Removal Eff. > 90 %60

Flue gas: 100Nm3/h

40
Flue gas flow rate: 100 Nm 3/h
Flue gas conc. 11.80%
Abs. flow rate: 7 L/min
Water circ. rate: 2.7 L/mino
Abs temp: 19 C

20

0
100

150

200

Time [min]

250

300

8
7
6
5

Product CO2 press. ~ 6.5 barabs

43

Flue gas flow rate: 70 Nm3/h
Flue gas conc. : 15.95%
Abs. flow rate: 3.8~4.5 L/min
Water circ. rate: 2.7 L/min
Abs temp: 19oC

2
1
0
80

120

資料13

160

Time [min]

200

240

Transfer capacity [g-CO2/g-soln.]

CO2 Product Abs. Press. [bar]

CO2 Removal efficiency [%]100

High pressure regeneration (Regen. T.: 123oC)
0.10

0.08

0.06

Transfer Capa. ~ 0.08 g/g

0.04

Flue gas flow rate: 70 Nm3/h
Flue gas conc. : 15.95%
Abs. flow rate: 3.8~4.5 L/min
Water circ. rate: 2.7 L/min
Abs temp: 19 oC

0.02

0.00
80

120

160

Time [min]

200

240

16

2.2 Amine-based absorption
Screen test for multi-functional absorbents in alkanol amine system

400

CO2

300

KIER-C3(14%)
KIER-C3
KIER-H2AMP
MEA

Temperature : 50 oC
Concentration : 20 wt%

SO2 Partial Pressure [ kPa ]CO2 Partial Pressure [ kPa ]Amino acid series, Hindered amine series, cyclic amine series, and etc.
Over 20 new candidates were tested for screening against existing absorbents (MEA,
AMP, etc.). Until now, KIER-C3 shows the best performance as a multi-functional
absorbent.

200

100

0
0 .0

0 .5

1 .0

1 .5

2 .0

2 .5

400

SO2

300

KIER-C3
KIER-H1
KIER-H2
MEA
AMP

Temperature : 50 oC
Concentration : 20 wt%

200

100

3 .0

CO2 Loading Ratio [ mole-CO2 / mole-Absorbent ]

0
0 .0

0 .5

1 .0

1 .5

2 .0

2 .5

SO2 Loading Ratio [ mole-SO2 / mole-Absorbent ]Materials

pKb

CO2
loading(CO2 mol/Amine mol)Abs. rate(k1/2/M)

AntiCorrosion(×10-3 mmpy)

MEA

4.140

0.82641.440761.14 (5 wt.%)

MDEA

5.160

0.83891.2030AMP

4.047

0.87601.688636.900 (20wt.%)

KIER-C3

2.853

3.08951.755023.487 (20wt.%)

Pilot plant

Flue gas flow rate ; max. 1,000 Nm3/hr
資料14 ; 5.0 ton-CO /day)(CO2 Recovery rate
2

3 .0

17

2.3 Absorption by K2CO3 solution
K2CO3(aq) + CO2 + H2O ⇔ 2KHCO3(aq)Solution: K2CO3/additive
Additive: increase of ionization rate of CO2 into solution
Absorption: 60oC,
Regeneration: 120oC
Energy ~ 600 kcal/kg CO2
Transfer capacity: 0.5-0.65 mol CO2/mol absorbent
Future plan: 350 Nm3/h pilot plant by 2012

Flue gas 10 Nm3/h

資料15

18

2.4 Fluidized bed adsorption using dry sorbent
K2CO3(S) + CO2 + H2O ⇔ 2KHCO3(S)Feed: 100 Nm3/hcoal power plant flue gasoAdsorption: 70 C,oRegeneration: 150 C
Product > 99 vol% CO2
Recovery > 80 %Future plan:
2,000 Nm3/h pilot plant by 2011

資料16

19

2.5 CO2 Membrane & Process
Single-channel Zeolite Membrane (L 100cm)
CO2/N2 [selectivity 50, permeability 8x10-7
mol/m2sPa- Shell & Tube Type Membrane Module(10Nm3/h)- Lab.-scaled Membrane Separation
System[10Nm3/h System][10Nm3/h Module]

Future plan (present ~ 2012)- Multi-channel Zeolite Membrane (2009)- Monolithic Zeolite Membrane (2010)- 100 Nm3/h pilot plant (2012)

資料17

2.6 Oxy-fuel Combustion20

CO2 capture tech. of combustion process by
the elimination of atmospheric nitrogen
Fossil fuel + oxygen → CO2 + H2O
CO2 recycle used for the control ofextra-high temperature of pure oxygen flame
Major applications:
Coal-fired power plant, Steel industry

KIER’s oxy-coal combustion facility

KIER’s results:
Oxy-coal(PC) burner development (0.1MW-class)

KIER’s oxy-coalswirl burner:
primary oxygen
direct injection
through multi-nozzle

CO2 capture: purity>95vol% (max. 98%), 3.2TonCO2/day
NOx emission < 60 mg/MJ

Future plan of KIER’s project
Oxy-coal boiler development
CO2 capture demonstration in oxy-coal boiler
by 2012 (0.5MW, 16TonCO2/day)

資料18

2.7 Chemical-Looping Combustor
•
•
•
•
•

Continuous operation of 50kWth CLC
CH4 conversion >99.7%
CO2 purity >98 vol%NOx < 10 ppm
Expected power generation efficiency: 53%

50kW chemical looping combustor
資料19

21

22

2.8 Pre-combustion capture• IGCC with CCS• CO2 capture cost $10/tCO2• Commercialization: 2030

CO2 storage

H2
power generation

Pre-combustion capture
H2 membrane
Membrane reactor for WGS rx

資料20

23

Development Schedule
Bench scale

Demonstration (20~30MW)

0.03MW post-comb. capture

Commercialization(100~1000 MW)

0.1MW oxy-fuel burner

2012

2009

2017

CCS for
EOR

Pilot plant
1 MW post-comb. capture
0.5 MW oxy-fuel boiler

資料21

2020

2050

CCS application for
New power plant

24

Thank you for your attention

資料22

（2）セッション１

資料23

An Outlook of China Coal’s Supply
and Demand

Chen Qi
Director of the Coordinating Department,
China National Coal Association

資料24

OutlineStrategic Position of the Coal Industry
Present Situation of China Coal Industry
Coal Demand in China Market
Supply Capacity of China Coal Industry

資料25

2

1 Strategic Position
As world’s largest producer and consumer of coal, China has
always been exploiting coal as an important energy source andindustrial raw material. During the last sixties, coal accounted
for more than 90% of Country’s primary energy, which was
only on the gradually decrease accompanied by petroleum
industry’s rise in the eighties of China. Nevertheless, the reserveof coal resources in China is much larger than that of petroleum
and natural gas, so coal, being relatively cheap, clean andreliable, now is and will still be the first choice for China, andthe coal-dominant energy structure is not supposed to change ina long period to come.

資料26

3

1.1The Proportion of Coal in China Energy Production
Year

Total Output of China
Energy(Ten thousand Tons ofStandard Coal)

The Proportion in the Total Output（%）
Coal

Petroleum

NaturalGas

Water,
nuclear, wind
and power

1960

17185

91.4

4.8

0.9

1970

30990

81.6

14.1

1.2

3.1

1980

63735

69.4

23.8

3.0

3.8

1990

103922

74.2

19

2

4.8

2000

128978

72

18.1

2.8

7.2

2005

205876

76.5

12.6

3.2

7.7

2007

237000

76.6

11.3

3.9

8.2

資料27

2.9

4

1.2 China’s Modernization and Energy Safeguard
As for the resource exploitation and utilization, now more than
90% of the resources used in China’s economic development
are supplied by the domestic market. Nevertheless, energy
safeguard—the issue of securing energy supply has always
been a hot and also a difficult point for China in its process ofmodernization. Recently, with the rapid growth of Chinese
national economy, coal, power and oil are all reduced to be inshort supply; consequently, both energy security and thesustainable development of economy are confronted withsevere trial.

資料28

5

1.3

China Energy Development Policy

Chinese government has formulated the policy of energy
development. That is, we should firstly and always abide by theprinciple of thrift and set our domestic market as the starting
point. Then on the basis of coal resources, we should develop adiversified and optimizing developing and consuming structure.
And we should establish a stable, economic, clean and safe
energy supply system. Coal industry is the cornerstone ofenergy security. Therefore, the proper way for development liesin the high resource utilization rate, guaranteed safety, higheconomic returns, little environment pollution as well assustainable development.

資料29

6

2

Present Situation of China Coal Industry

The year 2008 witnessed that: the output of raw coal reached 2.793 billion tons, an increase of 257
million tons compared with last year.
 the number of coal mines got to 14,000, with 5,52 millions of employedpeople.
 the number of death in mining accidents dropped to 3215, a decrease of
571 people compared with last year.
 the per capita income of coal enterprises reached 35,196 Yuan, 19%
increase compared with last year.
 the social inventory of national coal keeps at 201 million tons, 34%
increase compared with last year.
資料30

7

2.1 A Review of China Coal Production in 2008
In 2008, Southern China experienced a rare disastrous weather ofthe cryogenic freezing rain and snow storm, and Sichuan province
suffered the “May 12th” shocking earthquake. Greatly influenced bythose natural disasters, China’s coal production then became to fallshort of its demand for one time. In order to guarantee the normal
development of national economy, the large state-own coalenterprises, under the precondition of safety production, began tolend wings to coal production, which assured sufficient coal supply
in the market. After the disastrous earthquake attack in Wenchuan,
the coal production in Sichuan province as well as several otherprovinces surrounding was severely influenced, which led to thecontinuous rise of national coal price . When it came to the forth
quarter of the year, under the influence of international financial
crisis, coal demand of the market experienced a big downturn,which caused the quick drop of coal price and led to a large-scale
8
increase of coal inventory.
資料31

2.2 General Situation of China Coal Resources
China’s coal resources are rather affluent, widelydistributed among different areas of the country. Up to now,
the already-identified reserve volume reaches 1,1804 billion
tons, with the proven recoverable coal reserves being 1768
billion tons. The proven recoverable coal reserves in Shanxi,
Shaanxi, Inner Mongolia, Xinjiang and Guizhou can reach9561 billion tons, accounting for 81% of the total, which wins
their honour of leading coal producer.
資料32

9

Distribution of China Coal Resources
1:15,100,000

資料33

10

The Storage Situation of China Coal Resources
Categories

Storage Situation of Coal Resources

Burial Depth

Mines are usually deeply buried with quite complex structure, 36% of which areless than 300 meters, 45% between 300 to 600 meters, and 19% between 600 to1000 meter.

Coal-mine Gas

Mines with high gas and gas burst account for 21.87% of the total.

Coal Dust Explosion

Most of the mines has the risk of coal dust explosion.

spontaneous
combustion

72% of the large and medium-sized mines tend to ignite spontaneously quite easily.

Hydro-geology

About 25% of the large and medium-sized mines are situated among the complex
geological environments and 80% of the mines in North China are threatened by
O.L. water.

Rock Burst

About 5% of mines may be attacked by rock burst.

資料34

11

2.3

The Storage Condition of China Coal Resources

The storage condition for coal seams in China is quite complicatedand can easily get damaged from natural disasters. More than 94%
of the raw coal are exploited through well-drilling, only 6% of thetotal from open coal mines. High-level gas mines and doubleoutburst mines account for more than 20% of the total among thecountry. The average mining depth of the large and medium-sizedstate-own mines has been deeper than 400 meters, with 50 mines
getting to the depth of more than 1000 meters and some as deep as
1,300 meters. With the increase of mining depth, the impact of rockburst and ground temperature on safety production and labor
intensity has been increasing year by year.
資料35

12

The Increasing Trend of China Coal Production(2000-2008)

27.93

25
产量（亿吨）

Output (Hundred million Ton )

30
19.92
20

22.05

23.73

25.36

17.22

13.81
15 12.99

14.55

10
5
0

2000 2001 2002 2003 2004 2005 2006 2007 2008
年份 (Year)
資料36

13

China’s Leading Coal Producing Provinces and Large Coal Enterprises in 2008
OrderbyOutputProvinces(Autonomous
Regions)

Output(HundredMillion ton)

Order
by
OutputLargeEnterprises

Output（Hundred Million
ton）

1Shanxi

6.55

1

Shenhua Group

2.81

2

Inner Mongolia

4.72

2

National Coal
Group

1.14

3

Shaanxi

2.12

3Shanxi Coking
Coal Group

0.81

4

Henan

2.04

4

Datong Coal Mine
Group

0.69

5

Shandong

1.34

5

Huainan Coal
Mining Group

0.61

6

Guizhou

1.18

6

Shaanxi Coal andChemical Group

0.60

7

Anhui

1.17

7

Longmay Mining
Holding Group

0.55

8

Heilongjiang

0.97

8

Lu’an Group

0.42

9

Hebei

0.89

9

0.41

10

Yunnan0.86

10Zhong Ping
Energy ChemicalGroup
Yanzhou Coal
Mining Company
LimitedIn total

8.43

資料37

In Total

21.84

0.39
14

2008年中国煤炭出口 China Coal Export in 2008
单位Unit：万t Ten thousand ton
序号No.

国家与地区Country or Region

1-12月累计数量cumulative quantity (1-12)

4,543

1

韩国

South Korea

1,600

2

日本

Japan

1,300

3

中国台湾省 TaiWan Province

1,050

4

菲律宾

Philippines

112

5

土耳其

Turkey

105

6

印度

India

100

7

香港

Hongkong

47

8

朝鲜

North Korea

23

9

法国

France21

10

巴西Brazil

資料38

15

15

2.4

China Coal Economy’s Situation (Jan.-Jul., 2009)National output of raw coal reached 1.61 billion tons, an increase of 8.9% comparedwith that of last year.
The average selling price of raw coal by large coal enterprises keeps at 434.81 Yuan
per ton, an increase of 0.2% compared with that of last year.
The fixed asset investments in coal got to 145.8 billion Yuan, an increase of 39.6%
compared with that of last year.
National coal export totaled 12.92 million tons, a decrease of 57% compared with thatof last year.
National coal import totaled 56.87 million tons, an increase of 128% compared withthat of last year.
The number of death in mining accidents dropped to 1,175 in the first half of this year,
a decrease of 18.4% compared with that of last year.
By the end of June, the total social inventory reached 190.56 million tons.
資料39

16

3 Demand of Coal Market in China
According to the forecast by authority:
 In 2009, China’s coal demand is expected to be more than
2.9 billion tons.
 By 2015, China’s coal demand is expected to reach 3.5
billion tons.
 By 2020, China’s coal demand is expected to reach 3.8
billion tons.

資料40

17

3.1Demand Situation of China Coal Market (the first half of 2009)
In the first half of this year, China coal market experienced a situation of supply
exceeding demand. In detail, high-quality coal resources in the main coalproducing regions like Northeast China, Northwest Chins and Northern China
were quite tight; while coal supply in Southeast China and Eastern China wasrather sufficient and coal supply in Central China and Southwest China wasrelatively ample. As for the situation of the main coal-consuming industries, theconsumption in building materials and chemical industry got increased, theconsumption in steel industry held steady, while the consumption in electric power
got decreased. So generally speaking, coal economy run stably.
In the first half of this year, coal consumption ( used for power generation) in
the national electricity industry was 672 million tons, a decrease of 48 million tons
compared with that of last year. Coal consumption in the steel industry was 230
million tons, an increase of 3.5 million tons; Coal consumption in building
materials was 170 million tons, an increase of 12 million tons; while coalconsumption in chemical industry was 70 million tons, an increase of 3.5 million
tons.
資料41

18

3.2 The Slow Increase of Coal Demand (the second half of 2009)This year, thank to the policies and measures of “expanding
domestic demand and increase economic growth ”, China industrial
economy has reversed its downturn trend. Presently, theinternational financial crisis is still spreading worldwide and its
impact on our economy has not diminished. Therefore, there is nofundamental improvement in the external environment of ournational economic development. For instance, external demand still
keeps on shrinking, and the problem of productivity surplus in themain coal consuming industry still exists, which suggests the lack ofdrive in its rapid development. Besides, it is hard to change thesituation of supply exceeding demand, which exposes larger market
risk.
In the fourth quarter of this year, with the effects of government’s
macro-control measures getting bigger and the increasing demand
for steel, cement in infrastructure as well as the down-stream
products like industrial electricity, the coal demand is expected to19getincreased, but still be in a slow pace.
資料42

4

The Supply Capacity of China Coal Industry

With the reform and opening-up of China, its coal industry has
undergone rapid development, which has greatly improved its
coal industry’s supply capacity on one hand, and met thedemands of national economy’s sustainable and rapid
development. During these years, despite a surplus of the total
production during 1997-2000, China has ended the historicalsituation of supply falling short of demand, liberating national
economy from the restraint.

資料43

20

4.1

The Adjustment of China’s Coal Industrial Structure

The adjustment of China’s coal industrial structure has made great
breakthroughs and its economic development mode has been experiencingchanges. The organizing structure of coal industry has been greatly improved.
With the faster construction of large coal bases, some large regional coalenterprise groups are being established one after another. By the year 2008, thenumber of enterprises with the output of raw coal more than 10 million tons
reached 36. Besides, with the great decrease in the amount of mines, production
concentration degree is being continuously improved. At present, there arealtogether 469 large-scale coal mines with the annual production of more than 1.2
million tons, with the productivity of 1.423 billion tons. Among those large-scalecoal mines, there are 48 modernized mines with the annual production reachingten million tons (24 constructed and in production, with the productivity of 330
million tons and 24 under planning and construction, with the expected
productivity of 320 million tons ). The construction of large-scale modernized coalmines is the only way to realize the scale production as well as modernization ofcoal production, and the only way to improve coal supply safety and coal supply
capacity.
資料44

21

4.2

Further Improvement in China Coal Rail Capacity

Chinese railway authorities, in order to improve its coal rail capacity, are taking
the following measures:to improve the transport capacity of coal outbound channel by optimizing therunning route of railway;
to perfect the running organization of Datong-Baotou railway line after its
electrification;
to realize the large-scale increase of Gudiankou ( Inner Mongolia, Ningxia) coaltransport capacity as soon as possible;
to accelerate the pace of sending empty cars out of Shaanxi
to perfect the collecting, distributing and transporting system of DatongQinhuangdao railway line and Houma-Yueshan railway line, and realize its
further increase of 40 million tons in the coal transport capacity during the second
half of this year.

資料45

22

Ten Million Ton Coal Mines Constructed in 2008 (17 in total)
No.
Head Office

Mines’ name

1

神华神东

上湾煤矿

2

神华神东

哈拉沟煤矿

3

神华神东

补连塔煤矿

4

神华神东

保德煤矿

5

神华神东

榆家梁煤矿

6

神华神东

大柳塔矿大柳塔井7神华神东

大柳塔矿活鸡兔井

8

神华神东

石圪台煤矿

9

神华神东

锦界煤矿

10

神华金烽

万利一矿

11

神华宁煤

羊场湾煤矿

12

中煤平朔

安家岭二号井工矿

13

中煤平朔安家岭一号井工矿

14

山西同煤

塔山煤矿

15

山西晋城

寺河矿

16

安徽淮南

顾桥煤矿

Approved
Capacity(Ten thousand
Tons)

Output(Ten thousand
Tons)

Work Efficiency(t/per worker)

Per Capita
Income(Ten thousand
Yuan )/Growing
Rate(％)

Profitability Index(Ten thousand
Yuan )

21723
1300
1250
2006
1590
1852
1040
1130
1170
1000
1000
1545
1000
1000
1500
1080
1000

20618
1330
1205
2149
1547
1690
1100
1021
1034
782
1016
1203
1088
1087
1026
1073
1055

AVG 95.7

AVG 9.2

AVG 66087

157.86156.82150.1
132.9
126.63
125.2
124.8
112.8
85.8
58.68
19.81
136.23
102
81.75
16.93
20.22

9.59
13
11.3
11.94
13
8.6
8.6
11.01
8.54
6.29
6.6
9.98
8.5
9
6.2
6.94

103537150000101367
20111
51480
65994
61242
23240
11500
11947
31445
40008
41796
125976132912
76891
23

1212

18.07

6.97

74033

資料46

17

安徽淮南

张集煤矿

1260

Ten Million Ton Opencast Coal Mines Constructed in 2008
(7 in total)
No.

Head Office

Mines’ nameApproved
Capacity(Tenthousand
Tons)

Output(Tenthousand
Tons)

Work
Efficiency(t/perworker)StrippingRatio(m3/t)Per Capita
Income(Tenthousand
Yuan )/Growing
Rate(％)

Profitability Index(Ten
thousand
Yuan )

Open Coal Mines in Total

10900

11199

AVG

107.8

AVG
4.1

AVG
6.65

AVG
60342

1

神华准格尔

黑岱沟露天矿

2200

2284

150.283.77

6.48

166200

2

神华北电胜
利

胜利露天矿

1000

1085

129

2.73

5.22

12045

3

神华宝日希
勒

露天矿

1000

942

75.22

3.69

6.99

24777

4

中煤平朔公
司

安太堡露天矿

2200

2358

133.35

5.5

7.75

94509

5

中煤平朔公
司

安家岭露天矿

2000

1451

119.86

7.6

7.39

78000

6

华能伊敏煤
电

露天矿

1000

1383

79.72

1.91

6.45

13080

7

内蒙古霍林
河

南露天矿

1500

1696
資料47

67

3.54

6.26

33784 24

4.3 The New Production Record Set by China’s Mines in 2008
 Shendong Coal’s Bulianta Coal Mine, affiliated with Shenhua Group, is now

the largest modernized mine in the world. By employing the model of “one welland two faces”, it produced 21,487,000 tons of raw coal in 2008. The raw coal
output of its fully mechanized coal mining Team One has reached 12,074,300
tons per year, which has broken the annual records of both mining and working
face.
 Anjialing No.1,the fully mechanized coal mining team of Pingshuo Coal
Industry Company, by adopting the fully mechanized top-coal-caving techniques
at the thickness of coal seam 12.91 meters, has upgraded its monthly production
to 1,391,000 tons and daily to 71,798 tons, brushing both the monthly and daily
records of working face.
資料48

25

4.4 Premier Wen’s Thoughts on Coal Industry’s Further
Development
We should make great determination to
construct several large coal enterprise groups with 100 million ton
reserves,
realize the production of scale in coal mine, the modernization oftechnical equipment, the professionaliztion of staff members aswell as the informationization of management,
and establish the real modern coal enterprises.

資料49

26

Conclusions

As is proved by the development of china coal mine, theconstruction of large modernized mines guaranteed by
security and high-efficiency is the basis of establishing large
coal enterprise groups, which represents the developing
direction of the advanced productivity in the whole coalindustry and provides an fundamental outlet for China coalindustry to realize safety production.
資料50

27

Thanks!
Contact No.: 010-64463365(Fax available)
Mobile: 13683098107

資料51

28

OUTLOOK OF COAL DEMAND/SUPPLYAND POLICY IN INDIA2009 APEC CLEAN FOSSIL ENERGYTECHNICAL AND POLICY SEMINAR
12TH - 14TH OCTOBER 2009
INCHEON, KOREA
資料52

Presentation Sturcture Coal Sector Overview
 Demand profile Production Profile Strategic Initiatives
 Policy Challenges

資料53

2

Coal Sector Overview

資料54

3

Coal: World’s Fastest Growing Fuel
 Coal has been the world’s fastest growing fuel and coal use is expected
to grow faster than any other fuel far into the future Steep demand growth in China and India
7 Year Change in
Global Energy Consumption
CAGR

Coal

41%

2001 - 2008 Change

Natural Gas

3.0%

23%

Hydro

2.9%

22%

Oil

1.4%

10%

Nuclear

3%

0%

5.0%

0.4%

10%

20%

30%

Source: International Energy Outlook 2009, BP World Energy Report 2009資料55

40%

50%

4

Asia’s Most Important Fuel
 Coal remains a key source of energy in the world– Provides ~29% of global primary energy needs– Generates ~41% of world’s electricity
 Primarily used for power generation and metallurgy
 Cheapest source of energy on a heat adjusted basis
 Long term secular factors to drive global growth incoal demand– Growth driven by China and India ~50% of
global demand– Global demand driven by steel and powerindustries and higher cost of competing fuels– Asian growth driven primarily by power
generation needs
 Infrastructure and regulatory constraints, access to
low-cost reserves and higher cost structures
impacting supply
Source: BP World Energy Report 2009
1Mtoe= Million tonnes of oil equivalent= 1.5 metric tonnes of hard coal

資料56

Energy Consumption1 (2008)
Hydro electric
6.4%

Nuclear Energy
5.5%

Natural
Gas
24.1%

Oil
34.8%

Coal
29.2%

World 11,295 Mtoe

Hydro electric
5.3%
Natural
Gas
11.0%
Oil
29.7%

Nuclear Energy
3.0%

Coal
51.0%

Asia 3,982 Mtoe
5

Coal Industry in India
Coal Reserves in India

 Total resources– ~267bn tonnes: 106bn proved,
124bn indicated and 37bn inferred

China
Pakistan

 81% of production from opencast
mines; 19% from underground mines Coal present in 14 out of 28 states

Nepal

BhutanIndia
Myanmar [Indian coal is generally high ash,
~4500 GCV, low Sulfur]

Coalfields
Sri Lanka

Types of Coal Produced in India

Coal Production and Imports
552.0

600.0

Tertiary Coking
0.4%

500.0
Coking
12.6%

400.0

445.6

473.9

506.9

59.0

38.6
63.6

43.1
69.9

49.8
77.6

323.5

343.4

360.9

379.5

403.7

2004-05

2005-06
Coal

2006-072007-08
Others Imports

2008-09

411.6
29.0
59.1

89.3

300.0
200.0
Non Coking
87.1%

100.0
0.0

Source: Ministry of Coal, India; Coal India Management

資料57

6

Unparalleled Strategic Relevance The Indian economy expected to grow at 7.5% p.a. over the next 5 years– Access to electricity a core element to achieving this growth Energy demand growing at 7% per year
– Additional generation capacity of 79 GW1 by 2011-12 – of which 72%
coal-fired– Over 50% of Indians currently do not have access to electricity
 Coal contributes ~54% of commercial energy in India
Coal Consumption as % of Energy
Consumption in India2

Installed Capacity (GW)

Growth in GW in India

Hydro Electric
6%

250

: 6%
CAGR

200
150
100

69

85

105

211

Natural Gas
9%

132
Oil
31%

Nuclear Energy
1%

Coal
53%

50
0
1992

1997

2002

2007

2012E

Source: External Research, Ministry of Coal, Planning Commission of India
資料58
1Excludes Wind and Renewable Energy
2Mtoe= Million tonnes of oil equivalent= 1.5 metric tonnes of hard coal

Total = 433.3 Mtoe

7

Indian Coal Industry in Context
Per Capita Electricity Consumption Growth
in India (units per capita)

Global Coal Production by Country
3,000

2012

2,782

1,000

2006

2,500

582

2004
2001

408

1990

238

58% Growth in
XIth Plan

131

1980
1970

Million Tonnes

1

631

2,000

35

1950

18

1,063

993
1,000
500

84

1960

1,455

1,500

358

256

512

342

0
2002
USA

Electricity Consumption per Capita

Brazil

7,493 (2007)
2,444 (2007)

238

1

Billion Tonnes

FranceAustralia

India

300
250

10,347 (2007)

Australia

2008
China

RussiaGlobal Coal Reserves by Country

13,515 (2007)

US

China

402

327

200

157

150

115

106

100

76
34

50

2,024 (2007)

31

30
4

Source: International Energy Outlook

資料59

South
AfricaSouth
AfricaKazakhstan

UkraineAustralia

504 (2007)

India

Indonesia

China

631 (2006)

Russia

India

USA

0

8

Coal Reserves (as on 01.04.2009)
 Estimated Coal Resources - 267.2 Bt
 Coking - 33.4 Bt;
Non-coking - 233.8 Bt
 Proved Reserves – 105.8 Bt or 39.6%
 Coking - 17.5 Bt;
Non-coking coal- 88.3 Bt
 Remaining 161.4 Bt or 60.4% of resources to be brought into proved category
 Extractable reserves of about 55 Bt – may last for 50 years
with projected level of production.
 Estimated Lignite resources - 38.93 Bt–
Proved Reserves - 4.82 Bt (12%)

資料60

IMPORTANCE OF COAL RESOURCESIN INDIAIn power generation coal contributes 75%.

Power sector consumes 78% of total country’s
coal production.

Industries such as steel, cement, fertilizer,
chemical, paper and a host of other industries
also dependent on coal.
資料61

Actual and Projected Coal Demand during XI Plan

01-02
06-07
07-08
(IX Plan) (X Plan) (Actual)

Sectors

08-09
(RE)

09-10
(BE)

11-12
(XI Plan)

Power (Utility)

250.38309.38333.44378.00 397.54

483.00Power (Captive)

29.42

47.66

33.13

38.00

57.66

57.06

Steel
Oven

17.37

17.30

40.01

44.00

20.29

68.50

Cement

15.25

19.74

19.32

25.00

25.69

31.91

Sponge Iron

4.40

17.47

20.92

18.00

44.33

28.96

BRK & Others

37.76

55.52

60.293

52.00

58.93

61.58

Total

351.49463.87467.38555.00 604.44

731.00

&

Coke

資料62

Actual & Projected Coal production targets for XI Plan
Company

01-02 (IX
Plan )

06-07(X Plan )07-08
Actual

08-09
Actual

09-10
(BE)

11-12
(XI Plan)

ECL
BCCL
CCL
NCL
WCL
SECL
MCL
NEC

28.55
25.25
33.81
42.46
37.01
64.12
47.81
0.64

30.47
24.21
41.32
52.16
43.21
88.50
80.00
01.05

24.06
25.22
44.15
59.62
43.51
93.79
88.01
1.10

28.14
25.51
43.24
63.65
44.70
101.15
96.34
1.01

31.00
28.00
48.00
66.50
45.00
106.00109.30
1.20

46.00
30.00
78.00
70.00
45.00
111.00137.003.50

CIL-Total

279.65360.92379.46403.74435.00520.50

SCCL

30.81

37.71

40.60

44.54

44.50

40.80

Others327.65430.84

36.94

44.67

52.83

118.70Total

327.65430.84457.00492.95532.33680.00

資料63

Emerging Demand – Supply Gap in XI Plan
 Actual production from domestic sources - not likely toreach the envisaged level by the terminal year of XIPlan.
 Estimated demand based on existing linkages/ FSAs
and LOAs - outstrips estimated supply projections.
 Ggap likely to be wider than the gap projected byWorking Group.

資料64

IMPORT OF COAL
(Qty in million tonnes)

Non-coking coal Total of coking
andNon-coking coalYear

Coking coal

2004-05

16.92

12.03

28.95

2005-06

16.89

21.70

38.59

2006-07

17.88

25.20

43.08

2007-08

22.03

27.76

49.79

2008-09

24.00

35.00

59.00

資料65

Blocks allotted to New Players
Sector / End Use

No of blocks

Geological Reserves (MT)A. Public Sector Undertakings
I

Power

54

18676.11

II

Commercial Mining

407424.58

III

Iron and Steel3

1492.30

Total (I + II+ III)9727592.99(a) Power

294925.67(b) Iron and Steel

57.16

7316.77(c) Small and Isolated

2

9.34

(d) Cement

6.84

502.09(e) Ultra Mega Power Project7

2607.24(f) Coal-to-Liquid Project2

3000.00

Sub-total

104

18361.1120145954.10

B. Private Companies

Grant total

資料66

Key Strategic Initiatives
 Enhancing Availability ofTargeting: Sustainable

Resources Ensuring Accessibility ofDevelopment

Resources Growth Increasing Acceptability

 Profitabilityof Mining Practices
 Improving Profitability

 Efficiency

and Efficiency

資料67

16

Enhancing Availability of Resources
EXPLORATION Drilling targets increased 5x— Convert ‘inferred’ and ‘indicated’ category of reserves to‘proved’ category
 Carrying out detailed drilling and projectisation of coal blocks
allocated to captive block owners

COAL INVENTORY Exploration being carried out in systematic manner to arrive atreliable estimate of coal reserves
 Application of Information Technology to create geo database

PROJECTS New projects for ultimate capacity of ~325 Mty in public
sector New players to contribute ~450 Mty by 2016-17

FOREIGNACQUISITIONS

 Process of acquiring coal resources abroad through equity
stake in working or green field projects— Acquired 2 virgin coal blocks in Mozambique Global EoI floated for selection of strategic partners foroverseas operations
資料68

17

Presence Through the Value Chain
EXPLORATION

 Carried out in two stages: Regional and Detailed
 In 2008-09, 0.272mn meters of drilling has been achieved

COAL MINING CIL owns 473 mines– 279 UG
– 163 OC
– 31 Mixed
 SCCL and TISCO are the other main players in coal mining 201 blocks are allotted to public/private companies.

BENEFICIATION CIL operates 17 washeries ( 11 coking and 6 non –coking) CIL has taken a decision to supply beneficiated coal to all
consumers, other than those located at pitheads
 19 new washeries are being taken up for construction under
BOM with a total washing capacity of 105.6 Mty

資料69

18

Ensuring Accessibility of Resources
OPENCAST MINING

 Computer-aided mine planning for deeper OC mines Deploying high capacity equipment to achieve economies ofscale OITDS for efficient fleet management
 State-of-the-Art mass production technology being used

UNDERGROUNDMINING Tapping large reserves below 300m depth 7 UG Greenfield properties being developed 18 abandoned mines with estimated reserves over 1600 MT
identified for development

HIGHWALL MINING

 Mining of good quality thin seams
 Recovery of good quality coal in OC mines beyond economic
stripping ratio limit

CBM/UCG Recovery and commercial utilization of CBM from deep seatedseams
 Underground coal gasification of deep seated seams

資料70

19

Increasing Sustainability of Mining Practices
 Liberalized R&R policy for the Project Affected People (PAP) Supports 665 educational institutes in coalfield areas Provides medical assistance through 85 fully-equipped hospitals andnumerous dispensaries

SOCIALENVIRONMENTAL

 Setting up 19 washeries with a capacity of 105.6 Mty
 Started satellite surveillance for land reclamation andrestoration of OC mines 29 OCPs secured ISO 14001 (Environmental Certification)
 Planted ~70 million trees with survival rate of over 75%

Plantations and Greeneries over OB Dumps1

1 Left Picture: Plantation over OB Dump, MCL. Right Picture: Greeneries over OB Dump, Umrer, WCL
資料71

Source: Coal India Management

20Policy Initiatives
 Policy framework (operational guidelines) for
underground gasification notified.
 Guidelines on allocation of blocks for coal liquefaction
notified – 2 blocks since allocated to two companies.
 E-auction and forward e-auction of coal started.
 Policy on mine closure published – thrust on
restoration of land and funding for the purpose.
 Exploration – outsourced to new/ private players.
 Committee constituted to plan infrastructural support
to coal mining.
資料72

Policy Challenges
 Opening up of sector – removal of entry barriers :Group of Ministers constituted.
 Independent Regulator – draft Bill (legislation) circulated for inter-Ministerial consultation.
 Competitive bidding for grant of concessions – a Bill
(legislation) introduced in the Parliament.
 Listing of coal PSEs/ SOEs – for better corporate
governance and market discipline.
 Land use regulation – entire coal bearing area to bemapped, regulation of use for other purposes.
 New statute on land acquisition, resettlement & rehab.
資料73

Thank You!
資料74

COAL Demand/Supply Outlook in Korea
Oct.12 2009
Jae-Hyeok(Jason) Jang
hyeok@ewp.co.kr

資料75

Table of Contents

I.

Coal Demand in Electricity Industry

II.

Coal Demand in Steel Mill Industry

III.

Thermal Coal Demand Projection

IV. Coal Purchasing Strategy
V.

Things to be considered

資料761

Ⅰ. Coal Demand in Electricity Industry

資料77

Historical Trend in Coal Demand by Utility Companies(2002-2008)- Electricity Industry(Unit: Thousand Ton)
70,000KOSEP

KOMIPO

KOWEPO

KOSPO

EWP

60,00050,00040,00030,00020,00010,000
0

2002

2003

2004

2005

2006

2007

2008

Thermal Coal Import by Korean Gencos
Genco

2002

2003

2004

2005

2006

2007

2008

KOSEP

8,958

9,493

11,444

13,441

13,97615,037

17,269KOMIPO

8,644

7,894

9,577

8,352

9,064

9,018

11,029KOWEPO

7,453

8,257

9,161

8,609

8,465

11,026

11,953

KOSPO

8,280

8,475

8,805

8,806

8,894

8,848

9,789

EWP

6,869

7,273

7,580

8,448

10,254

11,223

13,837

TOTAL

40,204

41,392

46,56747,65750,65355,152

63,877

資料78
3

Historical Trend in Coal Demand by Sources(2002-2008)- Electricity Industry
70,000China

60,000Australia

Indonesia

28 %

31 %

36 %

40 %

26 %
2004

RussiaETCs

50,00041 %40,00030,00020 %20,00032 %10,000

19 %
31 %

37 %

44 %

2002

2003

0

40 %

45 %

34 %

27 %

34 %

22 %

17 %

17 %

11 %

2005

2006

2007

2008

Thermal Coal Import by Countries
Country

2002

2003

2004

2005

2006

2007

2008

China

15,061

18,142

12,106

10,330

8,587

9,172

6,931

Australia

12,893

12,984

16,88819,274

17,435

15,13521,996

0

0

0

0

130

302

1,083

Canada

1,418

742

280

417

811

1,112

1,482

Indonesia

8,004

8,021

13,207

14,981

20,241

24,847

26,120Russia

2,492

1,331

3,656

2,289

3,157

4,512

6,016

USA

336

171

431

365

291

71

249

TOTAL

40,204

41,392

46,56747,65750,65355,152

63,877

South Africa

資料79
4

Historical Trend in Coal Demand by Contract Types(2002-2008)- Electricity Industry(Unit: Thousand Ton)
70,000Term

Spot

60,00018 %50,000

23 %
20 %

14 %
40,000

23 %
27 %

24 %

82 %

30,000

77 %
80 %

86 %
20,000

77 %
73 %

76 %

2002

2003

10,000
0
2004

2005

2006

2007

2008

Thermal Coal Import by Contract types
Contract

2002

2003

2004

2005

2007

2008

Term

30,47530,23935,88541,04940,631

42,26052,098

Spot

9,729

11,153

10,682

6,607

10,022

12,892

11,779TOTAL

40,204

41,392

46,56747,65750,65355,152

63,877

資料80
5

2006

II. Coal Demand in Steel Mill Industry

資料81

Steel Production Demand & Capacity(Unit: Million Ton)

70
Demand

60
50
40

53

53

44

45

47

47

2002

2003

2004

2005

52

49

52

Capacity
56

57
55

60
58

64

50
44

38

30
20
10
0
2001

2006

2007

2008

2009

Steel Production Demand & Capacity
Contract

2001

2002

2003

2004

2005

2006

2007

2008

2009

Capacity

49

52

52

53

53

56

57

60

64

Demand

38

44

45

47

47

50

55

58

44

Source: Korea Iron & Steel Association
7

資料82

Historical trend in Coal Demand- Steel Mill Industry(Unit: Million Ton)

30

25
25

23
21

20
20

14

14

15

2001

2002

2003

21

19

19
13

15

14

10

5

0
2004

2005

2006

2007

2008

2009

2010

2011

2012

Contract

2001

2002

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

TOTAL

14

14

15

20

19

13

14

21

19

21

23

25

Source: GTIS, Macquarie Research, May 20098

資料83

III. Thermal Coal Demand Projection

資料84

Generation Capacity Mix Outlook by Fuel Typesz

The percentage of nuclear capacity is expected to increase by 8.2%, whereas that of Coal and LNG
are expected to decrease.
120,000

Nuclear

Coal

LNG

Oil

Renewable

Pumped/RCS

100,000
4.3 %

80,000

4.6 %23.0 %

60,000

3.6 %

7.4 %
24.6 %

7.1%

22.9 %

24.6 %

26.1 %
29.4 %

40,00029.2 %

31.4 %
33.4 %

31.8 %

20,00024.4 %

24.6 %

20092010

27.7 %

31.5 %

32.6 %

2020

2022

0
2015

Source: MKE (Electricity Supply and Demand Basic Plan #4 – Published in Dec 2008)
資料85
10

Generating Capacity / Electricity Generation Outlook- Coal-fired Power Plants Construction Plan
(Unit: MW)(Unit: GWh)
35,000250,000
Generating Capacity

Electicity Generation Outlook
200,000

25,000150,000

20,00015,000100,000

10,00050,0005,000
0Electricity Generation

Generating Capacity

30,000

0
2009

2010

2011

2012

2013

2014

2015

2016

2017

2018

2019

2020

2021

2022

Commisioning Schedule of New Coal-fired Power Plants
2009
Plant
Name(company)
Capacity(MW)2014

Hadong Thermal#8(KOSPO)

Yeongheung thermal#5(KOSEP)
Dangjin thermal#9(EWP)
Yeongheung thermal#6(KOSEP)Samcheok thermal#1(KOSPO)Samcheok thermal#2(KOSPO)
Dangjin thermal#10(EWP)

500

2,740

3,000

資料86
11

2015

Source: MKE (Electricity Supply and Demand Basic Plan #4 – Published in Dec 2008)

Thermal Coal Demand Projection(Unit: Million Ton)

90
78.6

80
70

73.2
65.4

66.4

66.4

66.4

66.3

67.7

2009

2010

2011

2012

2013

2014

76.9

77.7

76.4

73.3

71.0

70.4

2021

2022

60
50
40
30
20
10
0
2015

Conversion factor- Gross Calorific Value (as received) : 5,830 kcal/kg
12- Thermal efficiency : 41%

資料87

2016

2017

2018

2019

2020

IV. Coal Purchasing Strategy

資料88

Overview of KPX Syatem1: Revision on CBP (‘Cost-Based Pool’) Market
 As the suspension of TWBP (Two Way Bidding Pool) system is taking longer than expected, CBP system has
been continuously revised to reduce the power generation cost and to secure adequate reserves
 In May 2008, the Government implemented a revised CBP market by introducing a “The Adjusted Coefficientof SMP” in order to mitigate the impact on financial distortion among Gencos
Previous CBP Market

Revised CBP Market

Financial Distortion among
KEPCO & Gencos

The Adjusted Coefficient of SMP

IssuesSolution Sudden price hike in both energy& electricity market

 Introduction of a “The Adjusted
Coefficient of SMP”

9

Int’l oil price: US$85/bbl (Dec ‘07)
Æ US$105/bbl (Aug ‘08)

9

reduce the profit recognized fromintermediate / peak load generators

9

Electricity price: KRW99.78/kWh (Dec‘07) Æ KRW112.00/kWh (Aug ‘08)

9

Enhance the profit generated
from base load generators

9

Will particularly benefit EWP (2ndhighest base load capacity) Significant financial disparity among
Gencos Alleviate the financial disequilibrium
among Gencos provoked from using
different fuel type
資料89
14

Overview of KPX Syatem2: The Adjusted Coefficient of SMP
 Application of The Adjusted Coefficient of SMP
9 Abolition of Regulated Market Price (RMP) system
9 EWP can pass through 100% of its fuel cost through the energy price
9 Electricity Generation Cost Evaluation Committee annually determines The Adjusted Coefficient Power Price Comparison
Price type
Capacity
Payment(CP)

Old Price

Non Base LoadKRW 7.46/kWh

KRW 7.46/kWh

differentiated by regions, by seasonsand by hours

Min (SMP, RMP)

[Max {(SMP-Fuel Cost),0} x The Adjusted

EnergyNon Base Load

Remarks KRW 7.46/kWh as a base price, CP isBase Load

Base LoadPrice

New Price

SMP

Coefficient + Fuel
Cost]

 The Adjusted Coefficient
9 Nuclear : 0.3052
9 Coal : 0.1865
9 Anthracite : 0.75
9 Others/General : 0.3270※ RMP : Regulated Market Price, SMP : System Marginal Price

Introduction of “The Adjusted Coefficient of SMP” will motivate Gencos to procure the fuel with lower prices and lead tofair competition among Gencos. It will increase the efficiency of the power market by stimulating cost reduction

資料90
15

Striking Balance between Stable Supply and Economic
Purchasing: Effective Coal Procurement Management Diversification of Coal Sources-Canada, South African, USA Diversification Pricing Policy-Index linked, Option embedded

 Cooperation among Gencos-Unified coal procurement & negotiation-Cargo swaps

 Improvement of Low CV Coal Blending-Increase Low CV coal like Indonesian Enhancing Relationship with Suppliers-Try to increase term contracts

 Securing more Dedicated Vessels for Distant
Sourcing-FOB Spread b/w Newcastle and RBCT Investment in Coal Mine
-Off-takes

 Diversification of Coal Procurement Method-Direct Sourcing, Private Negotiation

Economical
Purchasing

Stable Supply

資料91
16

V. Things to be considered

資料92

Things to be considered 1: Nuclear Power Plants Construction Plan
Description

Locations of new Power Plants

Shin-Ulchin#1~4

Nuclear Power Plant

2010

Shin-Kori #1(1000)

2011

Shin-Kori #2(1000)

2012

Shin-Wolsong #1(1000)

2013

Shin-Wolsong #1,2

Shin-Kori #1~6

Getting support as CO2 free power plants

資料93
18

YEAR

Shin-Wolsong #2(1000)
Shin-Kori #3(1400)

2014

Shin-Kori #4(1400)

2015

Shin-Ulchin#1(1400)

2016

Shin-Ulchin#2(1400)

2018

Shin-Kori #5(1400)

2019

Shin-Kori #6(1400)

2020

Shin-Ulchin#3(1400)

2021

Shin-Ulchin#4(1400)

Things to be considered 2: Power Industry Restructuring Process
The power industry restructuring plan delayed and the former privatization plan for Gencos cancelled MOCIE
announced
restructuring
plan for powerindustry

1999





Incorporation ofgeneration companies

Cost-based pool bidding(“CBP”) mechanism

2000

Initiation of KOSEP
privatization

2001

2002

 IPO of KOSEP was
delayed Implementation of
TWBP was suspended
 Privatization plan for
Gencos cancelled

2003

2004

2005

2006

 Plan to separate KEPCO’s distribution sector was
halted due to substantial risk and uncertain
benefits from the separation plan

2007

2008

2009



Introduction of vesting contracts for
gencos deferredWholesale competition was put on a
hold

Cancellation of GENCOS Privatization Plan
 Privatization plan for KEPCO and its Gencos was cancelled in July 2008
 According to a reform plan for public firms by government, the plan has been completed to create amore efficient management structure and conducive environment for Gencos since 2008
資料94
19

Things to be considered 3: Active Cooperation among Gencosz’09. 2. 9. Inauguration of 5 Korea Gencos’ Unified fuel Procurement Sectionz’09. 6. 17. Unified Price Negotiation for Chinese coal of 2,600,000 MT (+/- 600,000 MT option)

Chinese Coal Price Negotiation
Total Chinese coal

Negotiation outcome

Performance evaluation

Settled quantity: 2.6M MT(U$83.12)
10.15 Million
MT

Lower than Japanby U$0.38/ton

Alternative
Buying : 6.95M
MT (U$73.23)

Lower than Chinese
Coal by $9.9/ton

Option quantity: 0.6M MT

Maximizing the flexibility+ U$1M+ U$69M+ Stability

PLAN: Expansion of the strategic alliances on purchasing into Australian & Indonesian coal COULD beconsidered.
資料95
20

Things to be considered 4: The Ratio of Dedicated Vessels VS Spot Vessels(Genco)z

Portion of Dedicated Vessel for Gencos coal transportation is expected to increase
8,000
85.50%
7,070

76.60%

80%70%

89.30%

88.70%

90%

62.50%

75.70%
6,390

80%

7,000

75.10%
6,000

67.10%
57.10%

60%

5,000
4,511
4,000

50%
3,371

40%

3,180

3,000

2,617

30%

2,500

2,128

20%

1,217

2,000

1,137

1,000

10%

-

0%
2001

2002

2003

2004

2005

2006

2007

Dedicated Vessel + CVC Vessel

2008

2009

2010

BDI Index

2001

2002

2003

2004

2005

2006

2007

2008

2009

Dedicated + CVC

62.50 %

90.50 %

57.10 %

76.60 %

88.70 %

89.30 %

85.50 %

75.70 %

75.10 %

SPOT

37.50 %

9.50 %

42.90 %

23.40 %

11.30 %

10.70 %

14.50 %

24.30 %

24.90 %

資料96
21

BD IINDEX

The ratio of Dedicated Vessel

100%Things to be considered 5: The Ratio of Capesize Vessel (Genco)z

Portion of Capesize vessel for Genco coal transportation is expected to increase up to over 60% by 2011
7,000

Coal Demand

Capesize Capacity

6,000

66 %
5,000

4,000

47 %

50 %
3,000

43 %
33 %

47 %

42 %

44 %

36 %

2,000

1,000

0
2002

TYPE

2003

2004

2005

2006

2007

2008

2009

2011

2002

2003

2004

2005

2006

2007

2008

2009

2011

12

12

16

18

18

18

22

24

24

Capacity of Capesize

1,500

1,500

2,000

2,250

2,250

2,750

3,000

2,750

4,375

Coal Demand

4020

4139

4657

4766

5066

5528

6388

6540

6640

# of Capesize

資料97
22

Coal Demand/Supply Trend &Coal Policy in Japan
October 12, 2009
Yoshitaka WATABE, Director for Coal Policy
Agency for Natural Resources and Energy
Ministry of Economy, Trade and Industry
Japan
資料98

1. Decrease in domestic production & increase in import
The volume of domestic coal production was approximately 50 million tons per

year in 1960s, which amounts to 75% of total coal consumption. However, atpresent it is around 1.3 million tons per year, which amounts to only 0.7% .
Japan heavily relies on import for coal.
（Thousand ton)
200000import coal

175000domestic coal

150000125000100000
75000
50000
25000
0
65

70

75

80

85

90

95

00

資料99

Source：”Energy White Paper 2008” Ministry of Economy, Trade and Industry, JAPAN05（Fiscal year)
12. World Coal Trade Japan is the world’s largest coal importing country, with imports amounting tonearly180Mt of coal, equal to one-forth of world’s hard coal trade.
Main coal importers

Main flows in global trade in coal (2007 estimates)

Rank

Country

Imports(m tons)

Share (%)

1st

Japan

182

20

2nd

Korea

88

10

3rd

Taiwan

69

8

4th

India

54

6

5th

U.K.

50

6

Total

World

892

100

Top 10 coal exporters

OthersKazakhstan 48m tons
23m
tons
Vietnam
(5.2%)
30m tons (2.5%)
Canada(3.2%)

30m tons(3.3%)
Australia
U.S.
244m tons
53m tons(26.6%)(5.8%)
China
Total coal
54m tons
exports(5.9%)
South
917.30m tons
Africa 67m
tons (7.3%)
Indonesia
Colombia
202m tons
67m tons Russia(22.0%)(7.3%) 100m tons

Other Europe
37.7Mt

22.6MtKazakhstan
22.6Mt11.8MtPoland 18.8Mt
Russia 11.
11.8Mt100.2Mt2M
11.3Mt62.7MttOECD Europe
257.9Mt
China
53.7.Mt13.0M Japan
182.3Mt
8.2Mt
t
16.4Mt35.9Mt
3.3Mt
30.5MtOther Asia
114.8Mt
270.1Mt29.7Mt
4.7Mt
Africa & Mid. East
21.5Mt136.6Mt
77.6Mt
5.7Mt
9.8Mt
51.6MtSouth Africa
66.7Mt9.4Mt

Other Europe
37.7M
t

Canad
a 30.4
3.2Mt
Mt 7.6Mt
8.8Mt
N. America
OECD Europe
48.7MtUnited States 257.9Mt
53.4Mt 19.0Mt
25.5Mt29.5MtColombia 5.7Mt
67.2MtIndonesia
202.2Mt

6.7Mt
Australia
243.6Mt

4.9Mt

Latin America
23.3MtNote 1: Volume of trade based on estimates for 2007.
Note 2: Exporting countries’ exports do not match total exports by destination due to statistical error.
Note 3: Quantities of less than 3 million tons are not shown.
Source: IEA, “Coal Information 2008”(10.9%)

資料100

3. Coal Import in Japan
The imported coal was used mainly for coking until 1970s. After the oil crisis, Japan
started importing coal for power generation.
The volume of imported coal for power generation has been increasing in the longterm, while coal for coking unchanged.
(Million ton)

Steam Coal

(Million ton)

Coking Coal

OthersIndonesia
RussiaSouth Africa

China
CanadaAustralia
U.S.

Source: “Trade Statistics” Ministry of Finance, JAPAN.
“Annual Report of Energy Production and Demand Statistics”
Ministry of Economy, Trade and Industry, JAPAN

Notice： The import volume of coking coal contains anotherusage besides the steel manufacturing usage.
資料101

3

4. Coal consumption in Japan
There was a shift of main fuel for electric power generation away from coal andtowards oil in 1960-70s. However, after the oil crisis, coal consumption for power
generation has been continuously increasing.
(Thousand ton)
200,000（Thousand ton）
100,000

180,000

90,000160,000

80,000140,000

70,000120,000

60,000100,000

50,00080,00040,00060,00030,00040,00020,00020,00010,000

0

0
65

70

75

80

85

90

95

00

05

Aggregate Demand(left-axis）
Coke（right-axis）
Ceramics andSoil/Rock(right-axis）
Steel（right-axis）
Electricity（right-axis）（Fiscal year)

Source： “Annual Report of Energy Production and Demand Statistics” until 2000
“Yearbook of the Current Survey of Energy Consumption”, “Annual report on electric power statistics” and “Handbook of Energy &Economic Statistics in Japan 2008”
資料102

4

5. Development of Environment Friendly Coal Utilization Technology in Japan


Japan, which depends for nearly 100% of its coal supply on imports, has been
making a continuous effort to develop and implement high efficiency coal-fired
power generation technology.
Development of High Efficiency Coal-fired Thermal Power Plants~ World’s Advanced Application of High Efficiency Plants ~資料103(Complied based on “The Thermal and Nuclear Power” of October 2006)

5

6. Comparison of clean coal technology between Japan and other countries
 Japan has been achieving the world’s highest thermal efficiency (41.6%) of coal-

fired power generation.
 The amounts of SOx and NOx emissions are the world’s lowest level.
Comparison of the thermal efficiency of coal-fired
thermal power plant by country

Comparison of the amounts of SOx and NOx
emissions in power generation by country〔g/kWh〕

4.9

5.0
4.0

SOx

3.9

3.7

2.6

3.0
2.0
1.0

1.7

1.9

1.5

NOx

4.0

2.0 2.0
1.7
0.7 0.6

0.7

0.2 0.3

0.0
U.S. Can ada Un ited France Ge rmany Italy(2 002) (2003) Kingdom (2 002) (2002) (2 002)
(2 002)

Ch ina(2 000)Japan(2 005)

Source: ECOFYS, “INTERNATIONAL COMPARISON OF FOSSIL POWER
GENERATION EFFICIENCY” (2008)

2006 results:
41.6% in Japan, 40.0 % in Germany, 36.7% in the UnitedStates, 35.9% in Australia, 32.1% in China, and 31.8% in India
資料104

Source ：OECD Environmental Data Compendium 2004, Energy Balances ofOECD Countries 2002‐2003
The Federation of Electric Power Companies of Japan (For data ofJapan only)67. Coal Use and Achievement of 3Es in Japan (Advantage of Coal)

Coal accounts for 20% of Total Primary Energy Supply in Japan, and is expected tomaintain a significant role.
Long-term Outlook for Energy Supply and Demand(Advisory Committee on Energy and Natural Resources in May, 2008)(unit: Kiloliter of Crude Oil Equivalent)
2010
Fiscal Year

Oil

1990
Results
265
52%

LPG

19
85
54

10%

Hydraulic Power

4%

Total

13

117

16

94

20

89

24

89

20

3%

3%

3%

4%

4%

508

587

584

583

568
資料105

107

24

87

22

79

22

129

1
26

123
94

26

99
19%

19

1

73
14%

99

3%

0%

95
18%

16%

19

18
3%

16%

99

3%

0%

19

20%

14%

19

1

146

183
35%

3%

19%

99

3%

0%

19

21%

18%

19

1

110

220
37%

3%

14%

99

3%

0%

18

20%

16%

19

1

121

245
36%

3%

14%

99

3%

0%

18

20%

15%

19

1

136

209
37%

3%

16%

83

3%

0%

19

21%

15%

19

1

113

232
39%

3%

16%

83

3%

0%

19

21%

15%

19

1

114

248
38%

3%

16%

83

3%

0%

18

20%

14%

19

1

117

218
38%

3%

16%

83

3%

0%

19

20%

95

223
39%

3%

14%

17

0

18

16%

69

3%

0%

New Energy, etc.

88

227
39%

20%

12%

22

Geothermal Power

123

15%

49

232

3%

21%

11%

Nuclear Power

18

2030

Additional Additional
Ongoing
Ongoing
Continuing Maximum
Continuing Maximum
Counter- CounterCurrent
Current
EffortEffortEfforts
Introductio
Efforts
Introductio
measuremeasure State Case
State Case
Lower Case Upper CaseCasen CaseCasen CaseLower Case Upper Case

40%

3%

17%

Natural Gas

255
43%

4%

Coal

2005
Results

2020

19
4%

1
0%

26

1
0%

38

3%

3%

4%

5%

4%

4%

7%

566

651

601

561

685

601

526

8. Increase of the Coal Use for Economic Growth in the World (Primary Energy)
 The world’s Total Primary Energy Supply (TPES) is expected to increase by approximately 45%

2006- 2030, out of which coal consumption is expected to increase by approximately 60%, andits share within TPES will increase from 26% to 29%.
 In particular, coal consumption is expected to double in China, increase 2.5 times in India andincrease by 15% in the United States. The main factor for such increases is growing demand forfuel for coal-fired power generation.
Outlook of TPES

• The world’s largest coal consumer is China (2.3billion tons), followed by the United States (1billion tons) and India (0.5 billion tons).
• In particular, China currently accounts for 38% of
global coal consumption, and is expected toincrease to 50% by 2030.
• Total amount of CO2 emissions of the three
countries are 12.6 billion tons, which accounts
for 45% of the global CO2 emission amount of
28 billion tons (2006).

Three countries - U.S., China, andIndia - account for 75% in 2030
資料106

Source: IEA, “World Energy Outlook 2008”8

9.Increase of Coal consumption for Economic Growth in the World (Power Sector)
 The share of coal consumption for power generation will increase from 41% to 44%

towards 2030. Coal is expected to be a major energy source for power generation as
it is today.

Outlook of Global Power Generation

資料107

Source: IEA, “World Energy Outlook 2008”910. New Development in the Clean Coal Policy of Japan 2009: Major Points of the Report by the Clean Coal Working Group
Aggressively promote technology development for the clean use of coal, which is experiencing global demand growth (“CoolGen” Initiative).
Contribute to alleviating global warming by applying Japan’s advanced coal utilization technology to the world (“Clean Coal for the Earth” Initiative).
＜我が国の石炭利用と３Ｅ達成＞
Increase in Coal Use for Economic Growth in the World○ Global coal consumption is projected to increase by approximately 60%
2006-2030.
○ Coal consumption in China: 2X; India: 2.5X; the U.S.: a 15% increase.
○ Coal-fired thermal power plants are to increase as a major source of power.
Crude oil
LNG
Coal

Japan has the most Environmentally Conscious Coal Utilization Technology○ Essential to continue the clean utilization of coal, which is economicallyefficient and stable in supply.
○ Many low-efficiency coal-fired thermal power plants exist in the world.
○ Measures by Japan for further high efficiency utilization of coal are thebest in the world.

•Coal prices are stable in the low•The share of coal in power
range.
generation in United States,•Reserve-production ratio of coal isGermany and otherlong and reserves remain abundant.
advanced countries is higher•Producing regions are dispersed andthan in Japan.
a stable supply may be expected.

•Many countries areplanning to develop a
number of new coal-fired
thermal power plants.

China

955 plants(by 2020;
estimated from theoutlook of installedcapacity, etc.)

UnitedStates110 plants

Germany

26 plants (by 2018)

UnitedKingdom

11 plants (by 2020)

Japan

5 plants (by 2020)•Japan’s coal-fired power
generation has achieved theworld’s highest efficiency.

Implementation of the “CoolGen” Initiative

Implementation of the “Clean Coal for the Earth” Initiative○ Practical applications of high efficiency coal-fired power generation
technology upon replacement in the future, thus realizing low carbon
emissions for coal-fired thermal power plants.
○ Furthermore, promote demonstrative research (the “CoolGen” Initiative) for
the realization of “Zero-Emissions Coal-fired Thermal Power Plants” by
combining IGFC with CCS, which aim to achieve ultimate power generation
efficiency.
○ Continuous effort for efficiency improvement is necessary to achieve thegoal of reducing CO2 emissions by half by 2050.

○ Positioning Japan as a place to demonstrate environmentally friendly
coal-fired thermal power plants as Japan possesses the world’s highest
efficiency coal-fired thermal power plants, and contributes to alleviate
global warming issues through disseminating this technology not only to
Asia but also to the entire world.
○ Simultaneous achievement of the 3 Es related to global coal use can beachieved by transferring the coal-fired thermal power technology to othercountries.

Enhancing the Multilayered Relations with Coal Producers○ Enrich government-level policy dialogues with major coal producers.
○ Construct multilayered cooperative relations with major coal producers.

Information Dissemination/Human Resources Development Regarding Coal Utilization○ Enhance information dissemination on the economic efficiency of coal, advanced
資料108 utilization technology, etc.
○ Human resources development of those who shall acquire the skills for coal andother resources development, and innovative coal use technology.

11. Implementation of the “CoolGen” Initiative~Realization of Zero-Emissions Coal-fired Thermal Power Plants with IGCC and CCS~
While maintaining the domestic infrastructure of coal-fired power plants, promote
the mixed combustion of coal and biomass for the time being, practical applicationof high-efficiency coal-fired power generation technology upon replacement in the
future to realizing low carbon emissions of coal-fired thermal power plants.
 Continuous effort for efficiency improvement is necessary to achieve the goal of
reducing CO2 emissions by half by 2050.


Efficiency Improvement of Coal-fired Thermal Power Plants

資料109

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

1112. Implementation of the “Clean Coal for the Earth” Initiative~From Japan to the World: Dissemination of Clean Coal Utilization Technology~
Simultaneous achievement of 3 Es (Economy, Energy Security & Environment)
related to global coal use will be achieved through transferring and promoting theapplication of the world’s highest efficient coal-fired power generation technologyof Japan to other countries.
 Highly efficient use of coal contributes to reduce the coal consumption and curbs
the decline of world’s coal resources.


Mt-CO2CO2 Emissions of Coal-fired Thermal Power Plants (2004)

2,500
2,000

（▲387）（▲776）▲387 (mil. tons)+ ▲776 (mil. tons)+ ▲184 (mil. tons)▲1.3 bil. tons

1,500
1,000

2,269

1,949
1,562

500
0

1,493

（▲23）

269

246

ExsistingCutting-edge
Application
Case

Japan
Japan

（▲184）

572
ExsistingCutting-edge
Application
Case

US
US

ExsistingCutting-edge
Application
Case

China
China

Exsisting388
Cutting-edge
Application
Case

India
India

In the case of applying the best practice (highest efficiency level of commercial power plants) of Japan to theexisting plants of each country.
資料110
Source: The Institute of Energy Economics, Japan (IEE JAPAN), Achievement data: World Energy Outlook 2006 (IEA)

By applying the bestpractices of coal-fired
power plants in Japan(highest efficiency amongcommercially operated
plants） to that of the U.S.,
China and India, reductions
estimated at 1.3 billon tonsof CO2 can be achieved
which is equivalent toJapan’s total CO2 emissions.

Note:

12

13. Implementation of the “Clean Coal for the Earth” Initiative~From Japan to the World: Dissemination of Clean Coal Utilization Technology~
China, the U.S., India, and EU countries including Germany and the United Kingdom are
gearing toward expanding their domestic coal use for power generation for energy
security and economic reasons. Therefore, it seems difficult to suppress their coalconsumption.
 Positioning Japan as a place to demonstrate environmentally friendly coal-fired thermal
power as it posses the world’s highest efficiency coal-fired thermal power, andcontributes to the alleviation of global warming through applying this technology not only
to Asia but to the entire world.


Diagram on Coal-fired Thermal Power Plant Efficiency in Japan and Technology Transfer

資料111

13

14. International Cooperation for the Promotion of Clean Coal Technology（CCT）
Japan has been carrying out－ International development & deployment of CCT－ Policy dialogues & seminars《Main Recent Events》【Multilateral 】【Bilateral 】(1) APEC (Expert Group on Clean Fossil Energy(1) China●Diagnosis of facilities, re-modeling & staff training●Cooperation on CCS－EOR (Carbon dioxide
Capture and Storage and Enhanced Oil Recovery)●Model projects of utilizing coal mine methane gas

Meeting)●Seminars & information exchange on CCT(2) India●Model projects for coal preparation systems(3) Indonesia●Coal policy dialogue & seminar(4) EU, Poland●Japan-EU CCS Workshop (Planned)●Japan-Poland policy dialogue & seminar (Planned)(2) ERIA (Economic Research Institute for ASEAN andEast Asia)●Research on CCT(3)APP（Asia-Pacific Partnership on Clean
Development & Climate: Power Generation &Transmission Task Force)●Peer review activities on the efficiency of aged coalfired power plants(4)MEF（ Major Economies Forum on Energy&Climate)●Drafting the Technology Action Plan of the “High
Efficiency and Low Emissions Coal Technology ”
資料112

14

Thank you!

資料113

15

（3）セッション 2A

資料114

Development of the Circulating Fluidized
Bed for the Energy Technology in Korea

2009.10.12.
APEC Expert Group on
Clean Fossil Energy
Dowon Shun
Korea Institute of Energy Research
dshun@kier.re.kr
資料115

New Energy with CFB Technology
SourceTechnology

Product
H2/CH4

Low rank coalGasification

FT
MeOH/DME

MTO/MTG

Gas turbine

DryingPC

USC-PC

CFBC

SC-CFB(PFBC)

Brown coalHyper coal/UCC

DCFC
Gas turbine
Diesel engine

Oil sandExtraction

Upgrading

Retorting
資料116

Syn. crudeResearch Field

資料117

CO2 absorption with Dry Sorbent Technology
Pilot scale test,
2000 Nm3/h
100 % CO

2

Clean gas without CO

100 Nm3/h

2

H 2O

‘08

Commercial level sorbent
Waste
Heat

‘05
2 Nm3/h process test facility
Met the target performancesof sorbent in the Lab

MH
CO

3

Regeneration

BoilerCarbonation
M C
2 O

3

Flue gas + CO 22000 Nm3/h demo. facility
by KIER(2010)

Sorb KX 40

資料118

Sorb TKX 35

Chemical Looping Combustion - KIER, Korea, 50kW
N2

CO2, H2O

M -> MOMO -> MAirHC

2nd generation

200kW by 2010
資料119

Development of Fluidized Bed Gasifier for Low Rank Coal
Gas

Ceramic
FilterCycloneSeparation

Screw Feeder

Pyrolysis Reactor

Coal Hopper

Clean-up

Tar/Oil
CO2

Char
CO2

Gasification of 1TPD of CoalChar Combustor@30ata 950C

Air Separator
O2
資料120

Research on CFBC
• Boiler design• Fuel variation• Diagnosis• Business consulting
10MWe commercial CFBC forRDF

2010
1MWe CFBC for RDF

1KWth Emission
Test unit

2007

0.1MWth Test unit

1991

1997

Tech service for CFBC, CJ
China

2007
資料121

Business consulting for
CFBC power plants

2008

Kier 1MWe CFB boiler for co-generation

The 8MWth and 1MWe capacity boiler designed and constructed by KIER
資料122

Upgrading of Low Rank Coal•Fluidized•Fluidized bed
bed coal
coal drying
drying technology
technology forfor low
low rank
rank coal
coal•Energy•Energy savingsaving multi
multi chamberchamber circulating
circulating fluidized
fluidized bed
bed
Pore plugging
Post treatment
DryingStorageHeat recovery

FeedingHeat supply

Pelletizing

DesignDesign andand construction
construction ofof aaCommercial
Commercial 500
500 ton/day
ton/day unit
unit

1ton/h by 2010
資料123

Coal drying technogy for coking coal•• Drying
Dryingandandpelletizingpelletizingcan
canimprove
improvecoke
cokequality
quality••Cokesstengthincrease
and
Low
grade
coal
Cokes stength increase and Low grade coalcancanbebeutilized
utilized••Multi
Multistagestageoperation
operationwith
withtrouble
troublefree
freeoperation
operation••AA 0.5ton/d
0.5ton/dtest
test unit
unit

Storage
Feeding

CycloneBag filter
Gas cooler
Fines

ClassificationAir
heating•• Moisture
Moisture 10->
10-> 2%
2%•• Low
grade
coal
Low grade coal mixing
mixing•• 250ton/h
250ton/h commercial
commercial unit
unit
資料124

Supercritical CFB
Large scale power
generation >500MWe
Substitutes ~ 500MWe PC
Maximum fuel flexibility for power
plant
From low rank lignite to
Anthracite
Low emission
High efficiency of 45% LHV
Chinese 600MW

EPRI-USA
資料125

LagizaIndustrial Field

資料126

Conventional

CFB Technology in Refineries
FCC Process in Refineries
Gas
Oils

Gasoline
Cycle Oils

FCC

FCC

C4-C8

OlefinCracking

C2=
C3=
OlefinOlefinRecovery
LPG
Light
Olefins

資料127

Distribution of CFB boiler in Korea

2,000
1,800

RDF
Coal

Steam rate(Ton/h)

1,600
1,400
1,200
1,000
800
600
400
200

資料128

20
12

20
10

20
08

20
06

20
04

Year

20
02

20
00

19
98

19
96

19
94

19
92

19
90

19
88

19
86

0

Fuel flexibility of CFBC
Low Emission
Flue gas
N2, O2, CO, CO2,

Brown Coal

H2O,Soot, SOx,
NOx

Energy

Steam

Waste
Power

Biomass

CFB Boiler

資料129

Waste to energy for metropolitan
10 Eco-energy sectors throughout the country

RDF factory

Cogen.

Industry

資料130

CFBC for RDF and Biomass
10MWe CFBC cogeneration facility for RDF
ü New concept for RDF
ü Core technology
ü Feedingü Bed drain
ü Emission
ü Corrosion prevention

Commercial scale CFBC with
fuel flexibility
Dispersed generation
ü Utilizing RDF, biomass, lowrank coalü

10 MWe CFBC for RDF

Municioal Waste(TPD)

Industrial Waste
(TPD)

Total

Capacity(MWe)Metropols

2,324

384

2,708

208

Cities

5,343

1,309

6,652

484

資料131

CFBC burning Low Rank Coal

Kumho Energy 300TPH CFBC

250TPH coal/TDF CFB
資料132

Wonju 10MWe CFBC for RDF

資料133

Brown coal upgrading
CHP

Utility

Subsitution
US$

Current use (Bitu. Coal)

5MT

57MT

-

2020

10MT

75MT

-

2015
(5,000ton/day=1.5MT/y)

15% Subst.

2% Subst.

100M

100% Subst.

20% Subst
Briquetting

1B

2020
(15MT/y)Dewatering

Ash separation•HHV 4500kcal/kg•Water 35~45%•Ash 2~5%

Pore treatment
資料134•HHV 6500kcal/kg•Water 3~10%•Ash 2~5%

Conclusions
Expectancy of near future market
ü Energy savings are desperateü Improved utilization of coal and new energy

required

CFB and be applied easily to marketable
technologies
ü Necessities can be integrated to produce newtechnologies
ü Market requires considerable economy andapplicable technologies

資料135

資料136

Datin Fatia Umar*, Bukin Daulay* andChiaki Suyama***R&D Center for Mineral and Coal Technology, Indonesia**JGC Corporation, Japan

2009 APEC Clean Fossil Energy Technical and Policy SeminarOct 12 ‐ 14, 2009, Songdo Convesia, Incheon, Korea
資料137

WaterAdditive

Stable during storage,transportation andcombustion

Coal

CWM
2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料138
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

FluidFuel oilsubstitution

CWM

Handling =heavy oilNo
spontaneous
combustion,no dust2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料139
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

x50
x3

Laboratory
scale•tekMIRA•JGC

Pilot plant•tekMIRA 1500 tpa•JGC, 3500 tpa

Demo‐plant
10.000 tpa
Indonesia,
JGC, Sinarmas

2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料140
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

Commercial
Indonesia 1 jt tpa

CWM Preparation• Raw coal
• Upgrading:
• UBC
• HWD

Additive• Surfactant/dispersant• Stabilizer

CWM Combustion• Initial temperature• Pressure• Air/fuel flow

2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料141
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料142
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料143
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

Pre heating 600°C

Combustion

CWM

Vaporization
900‐1,000°C

2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料144
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料145
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

Raw material:
Lignite: 48 wt%
Sub bituminous: 56 wt%
Bituminous: 60 wt%
UBC: 62 wt%
HWD: 62 wt%
Viscosity: < 1 Pa.s

Additive:
Surfactant/dispersant: 0.3 wt%
Stabilizer: 0.01 wt%

Combustion:
System: injection
Atomizer: Y jet type
Initial Temp. 600°C
Air/Fuel ratio: 2/1
Air Pressure: 3.2 kg/cm2

2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料146
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

Fuel

• MFO
• Heavy oil

Location• West Java
• DKI Jakarta• Banten• Sumatera Island(Lampung‐Sumut)

Industry• Food and beverages• Pulp and paper• Pharmacy• CPO2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料147
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

> 200industries

46
potential
industries

Need of
MFO: 245
MillionKL/year2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料148
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

The need of heavy oil (MFO) 2,45
million KL/year Rp 11.27 trillion

The need of CWM 4,9 juta
KL/year Rp. 7,350 trillion(MFO price = Rp. 4.6
million/kiloliter)(CWF price= Rp. 1,5
million/kiloliter)

Saving: Rp 1,225 trillion/year

Minimal capacity of CWM
commercial plant is 1 million
ton/year with investtment of
USD. 250‐320 million

2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料149
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

Demonstration Plant(10,000 t/y)

JAMBI
Commercial
Plant(1,000,000 t/y)2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料150
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

14

• The techno‐economic of CWM technology has been known and ready to
be applied to fulfill the energy demand in industries to replace heavy oil
or marine fuel oil.
• It means that several CWM commercial plants must be established inmany places in Indonesia, especially in South Sumatera, South and East
Kalimantan in where most of the low rank coal are presents.
• In order to commercialize the CWM process, a CWM demonstration
plant of 10,000 tons/year capacity as CWM model project will be
constructed soon.
• The establishment of the first CWM commercial plant with a minimal
capacity of 1 million tons/years or about 2,500 ton of coal/day is
expected in 2013 with an initial investment of about USD 250‐320
Million.
2009 APEC Clean Fossil Energy Technical and Policy Seminar
資料151
Oct 12 ‐ 14, 2009, Songdo Convesia, Incheon,
Korea

資料152

Role of Advanced Coal Cleaning Technologies
in Greenhouse Gas Reduction
2009 APEC Clean Fossil Technical and Policy Seminarby
Roe-Hoan Yoon, Jerry Luttrell and Robert Bratton

Center for Advanced Separation Technologies
Virginia Tech, Blacksburg, Virginia 24061
October 12-14, 2009

資料153
Center for Advanced Separation Technologies

CAST

GDP vs. Energy Consumption(Smil, 2003)
資料154
Center for Advanced Separation Technologies

CAST

Per Capita PPP vs. CO2
Consumption per Capita in 2007

資料155
Center for Advanced Separation Technologies

CASTGlobal CO2 Emissions in 2000

資料156
Center for Advanced Separation Technologies

CASTGlobal CO2 Emissions from
Fossil Fuels in 2006
(in metric tons)

資料157
Center for Advanced Separation Technologies

CASTIndia’s CO2 Emissions
Iran

Iran

South Korea

South Korea

U.K.

U.K.

CanadaCanadaGermany

Germany

Japan

Japan

India

India

RussiaRussia

U.S

U.S

China

China
0

2000

4000

6000

0

Million Metric Tons of CO2

5

10

15

20

25

Metric Tons of CO2 Per-Capita

Source: Wall Street Journal, Sept. 21, 2009
資料158
Center for Advanced Separation Technologies

CAST

Greenhouse Gas Emissions in
Developing Countries

資料159
Center for Advanced Separation Technologies

CASTIndia’s Coal Industry
Coal Production/Consumption
 4th largest coal reserve
 3rd largest coal producer 53% of energy consumption
 expected to double by 2030
 Poor Domestic Coal Quality
 typically 40-50% ash• low thermal efficiency• high transport cost
• large O&M costs

 government mandate• clean to <34% if transported >1000
km or if burned in sensitive areasImport Could increase 10-fold in 3 years.

資料160
Center for Advanced Separation Technologies

CASTCoal Reserves in India

資料161
Center for Advanced Separation Technologies

CASTAsh and Moisture on CO2 Emissions

資料162
Center for Advanced Separation Technologies

CASTImpact of Improving Efficienecy

1%efficiency→
2-3% CO2 reduction→
40% reduction possible

資料163
Center for Advanced Separation Technologies

CASTIndia’s Coal Industry


CO2 Emissions in India
 According to Friedman et al. (South Asian
Monitor, 2009), coal is “…the most polluting
fuel in terms of greenhouse gases andalready accounts for 65% of India’s CO2
emissions.” According to Couch (2002), India could“…reduce CO2 emissions to nearly 45% of its
present level using state‐of‐the‐art technologies
relating to coal quality, boiler/generator
design, instrumentation and control, and highvoltage distribution system.” (Couch, 2002)

資料164
Center for Advanced Separation Technologies

CASTCoal Cleaning Projects
Coarse coal cleaning Dry cleaning (or deshaling) $1 million from US Department of State Part of APP program No need to use water resources Lower cost compared to wet cleaning Simple to operate and maintain Fine coal cleaning Reduce ash content to below 8%
 Minimize import Grinding may be necessary Requires advanced separation technologies
 Contract under negotiation


資料165
Center for Advanced Separation Technologies

CAST

Eriez Air Table

Dry Cleaning Technology
 Deshaling process from
Eriez Manufacturing Essentially a vibrating air
fluidized riffling table Successfully applied U.S.
 Characteristics:• 50 x 5 mm feeds• <7% moisture feeds• ~2.0 SG cutpoint• Good efficiency(Ep=0.2~0.3)

SupportSuspension
Mechanism
Vibrator
Separating
Deck

Feed

Baffle
Plate

Air

Air
Chamber
Coal

資料166
Center for Advanced Separation Technologies

Middling

Rock

CAST

Impetus for Deshaling?
All coals contain “middlings”
that force a trade-off between
recovery and quality.
 How to clean to maintain aconstant fuel cost to boiler of$2.00/MM BTU?
 Assumptions
 Freight = $10/ton Coal
 Evaporation = $3/ton H20
 Ash Handling =$20/ton Ash Emissions = $200/ton SO2
 Other = $1.00/ton Coal

資料167
Center for Advanced Separation Technologies

Low Midds
Low AshHigh Recovery

High Midds
High Ash
Low Recovery

CASTImpetus for Deshaling?
Every coal particle sent to the consumer should have sufficient value to justify its
shipment (i.e., high ash particles result in negative payment).

Positive Value (Recover)
資料168
Center for Advanced Separation Technologies

Negative Value (Reject)

CASTImpetus for Deshaling?
Greenhouse Gas Emission
 Ash content has a large
impact on CO2 emissions.

Moisture
Contents

92

15%• High ash reduces thermal
efficiency.

• Added advantage of dry
coal cleaning.

 Note that emissions climb
rapidly >55-60% ash.
• Also tend to be high intrace elements (Hg),particulates, etc.

CO2 Index (kg/GJ)

 Excess water can also
reduce efficiency andincrease CO2 emissions.

12%
90
10%

88

4%

86

30

40

50

60

70

Ash (%)
資料169
Center for Advanced Separation Technologies

CASTIndustrial Application
Test

ProductAsh %Product
Yield %

% Ash
Reduction% Sulfur
Reduction% Mercury
Reduction

1

4.23

85.81

33.15

28.42

65.24

2

4.84

83.16

34.27

56.76

56.13

3

4.90

83.13

32.84

47.68

67.12

4

5.03

80.66

43.13

41.51

67.66

Clean

Middling

Reject

資料170
Center for Advanced Separation Technologies

CAST

Characterization of Indian Coals
No.1 (SI=47)

No.2 (SI=39)

No.3 (SI=40)

No.4 (SI=68)

No.5 (SI=73)

No.6 (SI=58)

No.7 (SI=74)

No.8 (SI=51)

No.9 (SI=34)

No.10 (SI=46)

No.11 (SI=65)

No.12 (SI=53)

No.13 (SI=52)

資料171
Center for Advanced Separation Technologies

Separation Index (SI)- Green – Good Candidate- Black – Not Certain- Red = Poor Candidate

CASTPilot-Scale Setup
Aryan Energy (Global Coal)

資料172
Center for Advanced Separation Technologies

CASTPilot-Scale Setup
Aryan Energy (Global Coal)

資料173
Center for Advanced Separation Technologies

CASTPilot-Scale Setup
Aryan Energy (Global Coal)

資料174
Center for Advanced Separation Technologies

CASTPilot-Scale Testing
Results from Aryan Energy

Cleaning
rejected >67%
ash material.

資料175
Center for Advanced Separation Technologies

CASTPilot-Scale Setup
Bhushan Steel & Power

資料176
Center for Advanced Separation Technologies

CASTPilot-Scale Setup
Bhushan Steel & Power

資料177
Center for Advanced Separation Technologies

CASTPilot-Scale Testing
Results from Bhushan Steel & Power

Cleaning
rejected >70%
ash material.

資料178
Center for Advanced Separation Technologies

CASTPricing Structure for Indian Coal

資料179
Center for Advanced Separation Technologies

CASTPricing Structure for
Steam Coal in India

資料180
Center for Advanced Separation Technologies

CASTMetallurgical Coal

Problem India’s coals are poorly liberated.
 Requires low ash metallurgicalcoal• <8% ash

 Fine grinding would help
• improves liberation• generates fines• costly and difficult

2 mm

資料181
Center for Advanced Separation Technologies

CASTSeparation Processes Used for Coal

CoarseMediumFine
Ultrafine

Increasing Difficulties

Size-Size

Solid-Solid
Dense Media
VesselSolid-Liquid
Dewatering
Screens

Raw Coal
Screens
Dense
Media
Cyclone

Sieve
Bends

BasketCentrifuges

Coal Spirals

Screen-Bowl
Centrifuges

Froth Flotation

Disc Filter

Classifying
Cyclones

資料182
Center for Advanced Separation Technologies

CAST

VT’s Advanced Technologies


Advanced Flotation
 Microcel flotation
 New FLS technologyAdvanced Dewatering
1. Dewatering aids
• Licensed to Nalco• Pinnacle pond recovery

2. Hyperbaric centrifuge• Licensed to Decanter• Field tests are ongoing

資料183
Center for Advanced Separation Technologies

CAST

Fine coal produces lower-ash coal.

Combustible Recovery (%)

100

80

60

40

Release Analysis
Assam Coal I
28 x 100 mesh-100 mesh-325 mesh

20

0
0

6

12

18

24

30

Product Ash (%)

資料184
Center for Advanced Separation Technologies

CAST

Domestic Coking Coal in India(Conceptual Flowsheet)

資料185
Center for Advanced Separation Technologies

CASTSummary
Advanced coal cleaning technologies can be used to reduce CO2
emissions.
 Up to 40% reduction is possible
 Most-Affordable Clean Coal Technologies for developing
countries.
 Virginia Tech has been working on Indian coals
 Steam coal

• Dry cleaning technology

 Metallurgical coal
• Fine coal cleaning technologies– Flotation– Dewatering

資料186
Center for Advanced Separation Technologies

CASTRESEARCH AND DEVELOPMENT
ON CLEAN COAL TECHNOLOGYIN INDONESIA
Dr. Bukin Daulay
Head of R&D Center for Mineral and Coal Technology
Agency of R&D for Energy and Mineral Resources
Ministry of Energy and Mineral Resources
Republic of Indonesia

Clean Fossil Energy Technical and Policy Seminar
Incheon, Korea, October 12-14-2009
資料187

ENERGY AND
MINERAL RESOURCES SECTOR

Source ofState Revenue

Feed Stocks

Economic
Development
Domestic Fuels

Sustainable
Development

Multiplier Effects

資料188

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

DISTRIBUTION OF COAL RESOURCES
Resources : 104,76 Billion ton
Reserves: 20.9 Billion ton

0.48
37,54
2.49
2.11

0.16
12.26

49.56

0.23

0.01

Source : Geological Agency, December 2008
資料189

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

TARGETED PRIMARY ENERGY MIX
2025

2005
Geothermal, 1.32%

Oil, 20 %Hydro, 3.11%
Natural Gas, 30%

Oil
51.66%NaturalGas,
28.57%

Alternatives
17%
Coal , 33%

Coal,
15.34%

資料190

Alternatives

Based on:President Regulation No. 5/ 2006
President instruction No. 2/2006

Bio-fuels, 5%Geothermal, 5%others, 5%
Coal Liquid 2%

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

ENERGY SUPPLY
INDUSTRIAL FEEDSTOCKDIRECT USE

CONVERSIONUPGRADING

Power Plants
Boilers/Burners
Non Fuel

Coal Liquefaction
Coal Gasification
Coke/Briquettes

UBC
Impur. Removal
Coal Water Fuel

ARDEMR
資料191

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

APPLICATION OF CLEAN COALTECHNOLOGY TO SUPPORT INDONESIANENERGY POLICY
Characteristics of New Coal Technology
9Suitable for Indonesian Low Rank Coals
9Low cost at high efficiency
9Environmentally Friendly
Clean Coal Technology to be considered :¾Coal Upgrading¾Coal Gasification¾Coal Liquefaction

資料192

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

COAL UPGRADING(Upgraded Brown Coal)

資料193

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

WHAT IS UBC?
To reduce moisture of LRC (up to 80%)
To increase CV of LRC (<5,000 kcal/kg) into a
product similar to HRC (>6,000 kcal/kg) basedon slurry dewatering process
Feed Stabilizer(Black box)

UBC
Premium Coal
(added value)• Coal Fired Power
Generation• Industry

Export

資料194

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-20098

DEVELOPMENT OF UBC PILOT PLANT
Bench Scale, Takasago (Japan),
100 kg/batch

Pilot Plant, Palimanan ,Cirebon, 5 ton/day
Function:• Test facilities to get engineering
data for commercial plant• Research, to develop UBC process• Operator training for UBC
commercial plant
Results: low rank coal with calorificvalue of <5,000 kcal/kg increased
up to >6,200 kcal/kg

Demonstration Plant
資料195

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009
9

UBC DEMONSTRATION PLANT(Satui, South Kalimantan)
1,000 ton/day feed or 600 ton/day productFuture program:-Optimize Test
- FS & Engineering Design- To Accelerate UBC
Commercial Plant

Construction: April 2007
Operation: Nov. 2008

資料196

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-200910

COAL LIQUEFACTION

資料197

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

COAL LIQUEFACTION TECHNOLOGY
Direct liquefaction

Coal

Gasification andshift reaction
CO + H2

Decomposition
andHydrogenation

H
H
Oil

Indirect liquefaction
F/T
Synthesis
資料198

CxHy
Oil orChemicals

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

COAL LIQUEFACTION TECHNOLOGYUNDER COMMERCIALIZATION Fischer-Tropsch synthesis (SASOL PROCESS)- Indirect Process- Commercially Available Headwaters Technology Innovation (HTI)- Direct Process develop by US- Commercial Plant under construction in China- F/S in Philippine and India

 Brown Coal Liquefaction (BCL)- Direct Process develop by Japan- Pilot plant in Victoria Australia- F/S in three locations in Indonesia (Banko,
Berau and Mulia)
資料199

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

ROAD TO COMMERCIALIZE BCL TECHNOLOGYPSU 1 t/dResults of 50 t/d
Pilot Plant in
Victoria

Demo Plant
3,000 t/dCommercial Plant
6,000 t/d

Too Risky

Proposed Demo Plant
Capacity 3,000 t/d or 13,500 bbl/d
Investment 1.5 billion USD

資料200

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-200914

EFFORTS TO REALIZE COAL
LIQUEFACTION DEMO PLANT
 1994 - 2001 Research Collaboration Indonesia-Japan 2001 - 2002 Pre F/S of three locations
 2006 - GOI has issued the Presidential Decree No. 5/2006 andPresidential Instruction No.2/2006- Roundtable Meeting I & II in 2006
- Joint Statement between METI and MEMR (both GOI and GOJ
agree to develop coal to liquid and GOJ intends to donate PSU)
 2007 - Establishing a Working Group (Consortium and Technical Teams)
 2007 - Update F/S Mulia Coal
- GOI and Indonesia private companies agree to participate fordemo plant construction
 2008 - Preparation of Joint Development Agreement for CTL
commercialization between Indonesia and Japan (no progress due
to technology guarantee obstacle ) 2009 – Proposed to Japanese Gov. for constructing PSU of 1 ton coal/day
資料201

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-200915

COAL GASIFICATION

資料202

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

COAL GASIFICATION TECHNOLOGIES
Tigar

TexacoShell

Fluidized

Entrained

Entrained

Operation Temp. 800-1,000>1,400>1,500Oxidizer

Steam

OxygenOxygenCoal Feed

CoarseSlurryPowderResidueDry ash

Slag

Slag

Type

Fixed bed gasifier was excluded due difficulty to maintainpermeability in the gasification of lignite
資料203

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

TIGAR GASIFICATION TECHNOLOGY• MoU between ARDEMR, PT Pupuk Sriwijaya, Ishikawajima-Harima

Heavy Industries Co. Ltd (IHI) and Sojitz Co. concerning “Study on
Integration of Lignite Gasifier into Fertilizer Plant (Oct. 18, 2006)• Study on Integration of Lignite Gasifier into Fertilizer Plant using

TIGAR (Twin IHI Gasifier) Technology has been carried out and the
Final Report (Feasibility Study) completed in June 2007•

The Final Report concluded that:- It was feasible to integrate lignite gasifier into existing fertilizer plant- To construct a prototype plant in PT Pupuk Kujang, Cikampek
to obtain detail engineering and economic data

• The Draft of Cooperation Agreement on TIGAR Prototype Plant isbeing prepared, including: Utility list, Schedule of project, Scope ofwork for EPC and operation, project cost, and Commitment ofcontribution• IHI will change/delay schedule of syngas commercialization for

flexibility of site condition of commercial plant, ensuring quality &safety and understanding impact of lignite characteristics
資料204

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

ADVANTAGES OF TIGAR GASIFICATIONTECHNOLOGY
1. Low
Temperature

Insensitive to content ofcoal moisture and ash orsuitable for lignite

2. Employ Steamas Oxidizer

High Concentration of H2
suitable for ammonia plant

3. Coarse anddry coal feed

Reduce Grinding Cost andhigh energy density

4. Separation between
combustion andreduction Zone

Low Cost of CO2
Capture
資料205

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

SCHEDULE OF SYNGASCOMMERCIALIZATION
2007

6 t/d
Pilot
plan
50 t/dPrototype
Plan

Commercial
Plant

2008

Testing

2009

2010

2011

2012

2013

2014

2015

2016

Plant modification
and Testing
DesignModification
and additional Operation
Construction
Operation
Design & Construction
TIGAR for fuel use
Design & Construction
TIGAR for Chemical use

Procurement

2009/10/19
2009/10/19
資料206
Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

COAL WATER MIXTURE

資料207

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009

CWM ACTIVITIES 1992-1996, CWM preparation using low rank

coal and bituminous coal
 1996-2000, CWM preparation and combustion
test using bituminous coal
 2003-now, CWM preparation and combustion
test using upgraded coal by UBC process 2006-now, R&D of CWM joint cooperation
with JGC (Japan) to develop HWT-cs
 2008-now, study market on CWM utilization
資料208

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-200922

Immediate Objectives
To obtain an HWT-cs demonstration plant of 10,000
tons/year capacity to show the itself and CS combustion
to candidate user in Indonesia.
Long Term Objectives- To increase the value of Indonesian low rank coal
- To prevent the secure and stability of energy supply- To substitute for fuel oil

資料209

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-200923

CONCLUDING REMARKS
Indonesia will more relying on coal to fulfill domesticenergy demand.
Indonesia is interested in developing clean coaltechnology for low rank coals utilization, sometechnologies (Coal upgrading, liquefaction,
gasification and coal water mixture) now ready forcommercialization.

資料210

Clean Fossil Energy Technical and Policy Seminar, Incheon, Korea, October 12-14-2009http://www.tekmira.esdm.go.id

資料211

Principles of NOx Control and Traditional LowNOx Burners
Traditional Low-NOx burner

資料212

烟台龙源电力技术股份有限公司

Yantai Longyuan

Composition of Plasma Dual-scale
Low-NOx Combustion System
Plasma dual-scale low-NOx combustion system
consists of Plasma burner and Dual-scale
combustion technology

資料213

烟台龙源电力技术股份有限公司

Yantai Longyuan

Plasma Low-NOx Burnerp

Nitrogen forms into amino-type nitrogen radicals（HCN,NH3,CN) as thevolatiles are released from coal. The ignition process occurs inside theplasma burner, therefore the oxidants concentration is low (Excess air
coefficient:α ＜0.3) and the early stage of combustion occurs in strong
reductive medium. The amino-type nitrogen radicals transform into N2
instead of NOx.


NOx
Fuel Bound
Nitrogen

HCN
NH3
CN
N2

資料214

烟台龙源电力技术股份有限公司

Yantai Longyuan

Plasma Low-NOx Burner

Secondary air
Recirculation
zone

Secondary air

Burnoutzone

等离子发生器Volatile release, combustion zone, NOx reduction zone
Plasma arc

Secondary air
Secondary air Spin vane

Primary air and coal
資料215

烟台龙源电力技术股份有限公司

Yantai Longyuan

Plasma Low-NOx Burner

Rapid release of volatiles, fast
combustionp

Fuel staging combustionp

Air staging combustionp

Reduction within flame

Deep reduction combustion
within flame, low oxygen, with α
between 0.2-0.35

Larger reduction zone of NOx

Relatively lower averagetemperature in combustion zone,
between 800-1100℃
資料216

烟台龙源电力技术股份有限公司

Yantai Longyuan

Dual-scale Combustion TechnologypDual-scale combustion technology is the combination and organization ofproper utilization of furnace Space and pulverized coal combustion Process.

pSpace scale. On the horizontal plane, unique air and coal streams form

p

p

p

into two zones: the central zone and the near wall zone. The two zones eachhas distinctive characteristics of temperature, fluid flow and flue gas content
field. On the vertical plane, there are two reaction zones.
Process scale. Process scale emphasizes the distinction of threefields’(temperature field, fluid flow field, flue gas content and density field)
characteristics at critical stage of combustion. This includes the ignition
process, flame spread process, burn out process. The flame brim iscontrollable.
The vertical and horizontal reaction zones effectively control the NOx
formation and reduce fly ash carbon.
Highly stabilized combustion, low-NOx, slagging prevention, better
adaptability to different types of coal.

資料217

烟台龙源电力技术股份有限公司

Yantai Longyuan

Dual-scale Combustion Technology– Main principles of dual-scale combustion technologypPrinciple of high efficiency and Low-NOx emissionpPrinciple of effective slagging preventionpPrinciple of highly stabilized combustion

資料218

烟台龙源电力技术股份有限公司

Yantai Longyuan

Dual-scale Combustion TechnologyPrinciple of High Efficiency And Low-NOx Emission•

Highly staged air and low oxygen combustion process•

Enlarged reduction zone and reduction combustion zone•

Increased boiler efficiency

三维浓淡示意图纵断面浓Dense coal zone
煤粉区
of vertical plane

Burn out zone燃烬区氧化区 zone
Oxidation
还原区

Reduction zone

Dense coalzone of
横断面浓
horizontal
plane
煤粉区

纵断面淡
Sparse coal zone
煤粉区
of vertical plane

Sparse横断面淡coal zone
煤粉区
of horizontal
plane

Burn out zone燃烬区氧化区 zone
Oxidation
还原区

Reduction zone

Schematic diagram for two reaction zones

烟台龙源电力技术股份有限公司

資料219

Schematic diagram for pulverized coal density in furnace

Yantai Longyuan

Dual-scale Combustion Technology－
Principle Of Effective Slagging Prevention

近壁区
Near wall zone
Central zone
中心区

炉膛燃烧器区域

Near wall zone
近壁区
Central zone
中心区

Combustion area

資料220

烟台龙源电力技术股份有限公司

Yantai Longyuan

Dual-scale Combustion TechnologyPrinciple Of Highly Stabilized Combustion

General stabilized
combustion circulation

复合稳燃大涡

Stable combustion

着火稳定驻涡
circulation

Thermal reflux

接力热回流小涡circulation

炉膛燃烧器区域

General stabilized复合稳燃大涡
combustion circulation

Thermal reflux
circulation
接力热回流小涡Combustionarea

Stable combustion

着火稳定驻涡
circulation

Thermal reflux
接力热回流小涡circulation

Thermal reflux
circulation
接力热回流小涡

資料221

烟台龙源电力技术股份有限公司

Yantai Longyuan

Demonstration Project of Plasma Dual-scale LowNOx Combustion Technology
Datong No.2 Power Plant
Before Retrofit

After Retrofit• Poor adaptability to coal,partial slagging in the
furnace, temperature fieldbias, over-temperature of
reheating surface.
• Steam temperature varies
greatly when slagging or
soot-blowing.
• More than 100℃
temperature spread
between the two sides ofboiler.
• NOx emission of 1120
mg/Nm3.
• Boiler efficienc: 90.87％.

• Slagging problem solved, thereheating surface
temperature back to normal.
• No need for soot blowing.
• NOx emission of 300340mg/Nm3,, CO: 35ppm,
fly ash carbon: 3.3%.
• Remarkable reduce of plantelectricity.
• Boiler efficiency:92.15%• adaptability of Coal.
• Stable low-load combustion,
capable of stable combustion
at 50% of full load.

資料222

烟台龙源电力技术股份有限公司

Yantai Longyuan

Demonstration Project of Plasma Dual-scale
Low-NOx Combustion Technology
Shenzhen Mawan Power Plant
Before Retrofit

After Retrofit
改造前后对比表• No slagging in furnace,complete combustion of
Shenhua coal.
• NOx emission within
128～181mg/m3• Fly ash carbon content:
2.63～2.99％• Boiler efficiency: 93.24％～93.44％• Severe slagging in the
furnace, incomplete
combustion of Shenhua
coal.
• NOx emission exceeds
700mg/m3• Fly ash carbon content:
7%• Boiler efficiency:
91.5%～93.2%

資料223

烟台龙源电力技术股份有限公司

Yantai Longyuan

Characteristics of Plasma Dual-scale Low-NOx
Combustion Technology

p

p

p

p

The plasma dual-scale low-NOx combustion technology reduces
TPS NOx emission to below 200mg/m³ without boiler efficiency
loss.
Combines low-NOx combustion with fuel-oil free technology,
which brings general effect of energy-saving and environment
protection.
Reduces NOx emission while keeps the cost-effective and safe
operation of boiler.
Slagging prevention, stabilized combustion and increased burnoff rate.

資料224

烟台龙源电力技术股份有限公司

Yantai Longyuan

Development of China TPS and Technology Demand

Plasma Fuel Oil-free Power Plant Technology

Plasma Dual-scale Low-NOx Combustion Technology

Utilization of Plasma Technology in Other Fields

資料225

烟台龙源电力技术股份有限公司

Yantai Longyuan

Utilization of Plasma Ignition Technology inCement kilnpTraditional ignition of rotary
cement kiln: wood, oil gun.

p

Plasma ignition technology
ignites pulverized coal without
fuel oil．

資料226

烟台龙源电力技术股份有限公司

Yantai Longyuan

Characteristics of Plasma Ignition
Technology for Cement KilnpSafer and more reliablep

Stabilized combustionp

Convenient for adjustmentpFlame more evenly disposed,
helps protect kiln bricks.

pMore environment-friendlyp

No oil system, single fueloperation
資料227

烟台龙源电力技术股份有限公司

Yantai Longyuan

THANK YOU!
Yantai Longyuan Power Technology Co.,Ltd
Zhang Yonghezhangyonghe@lypower.com.cn
http://www.lypower.com

資料228

烟台龙源电力技术股份有限公司

Yantai Longyuan

（4）セッション 2B

資料229

Guidelines for CCS-Ready Power Plants in
Developing APEC Economies(EWG 01/2008A Project Preliminary Report)
Rod Boyd
Amir Tadros
Tony Barnwell

資料230

Scope of presentation• APEC project EWG 01/2008A scope / objectives / status• Definition of ‘carbon capture ready’• Regional coal fired power plant construction• Potential for case study plants• Capture ready guidelines• Plant layout considerations

資料231

APEC project background• Expanding coal-fired power generation in the APEC region• Global climate change issue• In 2007 APEC leaders agreed to promote policies that
advance clean coal technologies and in particular carbon
capture and storage (CCS)• In 2008, G8 leaders stated “We strongly support therecommendation that 20 large-scale CCS demonstration
projects need to be launched globally by 2010 ....”

資料232

APEC project objectives•

Present issue for power sector is whether to consider, as
part of the design of new plant, the ability to capture andstore CO2 – in the future.

•

This is so called ‘capture ready’ concept

Project Objectives:•

Present case studies of projects in early siting & planningstage that are made ‘capture ready’•

Develop guidelines for planning & cost assessment
related to making new coal-fired plants ‘capture ready’

資料233

APEC project scope• Review issues that may impact the development ofcarbon-capture ready power plants.
• Identify the information needed to define CO2 CaptureReady specific to APEC developing economies• Identify suitable power plant projects in the early siting,planning, and design stages can serve as case studies• Develop a set of planning & cost assessment guidelines
for making new coal-fired power generating plants CO2
capture ready.

資料234

Progress to date
• Conducted review of definitions of ‘capture ready’• Identification of new coal fired plants planned for theregion; comparison with potential CO2 storage sites• Identification of features of candidate plants to be included
as case study• Identified 8 potential case study plants in China• Established a ‘typical’ new plant specification for region• Plant modifications required for ‘capture ready’• Preliminary site layout guidelines
資料235

Definition of ‘capture ready’• No universal definition yet; since 2004, various definitions have been
proposed• IEA definition is practical and recognises transport & storage facets:– “It is one which can include CO2 capture when necessary regulatory
or economic drivers are in place”– “….. all known factors in their control that would prevent installationand operation of CO2 capture have been identified and eliminated.
This might include:• A study of options for CO2 capture retrofit and potential preinvestments• Inclusion of sufficient space and access for additional facilities
that may be required• Identification of reasonable route(s) to storage of CO2.”

資料236

Coal fired plants planned in the region• Coal use in developing APEC economies is rising rapidly• Survey conducted of coal fired plants at the planningstage• APEC Economies surveyed:– China– Indonesia– Malaysia– Thailand– Philippines– Vietnam

資料237

Coal fired plants planned in China

Unit capacity

Total
no.

greenfield

135 to 350MW

47

600 to 700MW

steam conditions

flue gas

USC

SC

Sub-crit

N/A

FGD

DeNOx

20

0

2

32

13

44

20

37

15

4

27

3

3

30

12

>1000MW

21

9

19

0

0

2

17

8

Totals

105

44

23

29

35

18

91

40

•
•

105 coal fired plants currently planned or under construction
37% planned to have both FGD & DeNOx

資料238

CO2 storage potential in China
In 2005, an APEC project
identified potential
storage basins in China

資料239

Case study plant selection criteria–

Project timing: post 2014 start up: ‘capture ready’decision must be made at site selection stage.

–

Proposed site: Unless brownfield involves demolitionof old units, greenfield sites better–

Plant specification:––

Planned installation of FGD and DeNOx–

Larger unit size (>600MW)–

Supercritical steam conditions

Plant location: proximity of the proposed plants to
CO2 storage locations or CO2 hub

資料240

Shortlist of potential case study plants (China)that meet above criteria and are close to geological storage:basinprospectivity

distance(km)

Bohai WanHigh

0

2x 600MW

Subei Yellow Sea

High

25

Jilin Baicheng

2x 600MW

SongliaoHigh0

Guodian Shangqiu Mingquan

2x 600MW

Taikang Hefei

Intermediate0

Bohai Wan

High

25

Taikang Hefei

Intermediate0

Bohai Wan

High

25

Taikan Hefei

Intermediate0

Bohai Wan

High

150

Taikan Hefei

Intermediate0

Bohai Wan

High

350

Subei Yellow Sea

High

300

plant namecapacity

Henan Taisu Mengjin

2x 600MW

Datang Nanjing Xiaguan

Minquan Phase 1
Henan Pingingshan
Guodian Xingyang
Shanghai Caojing

2x 600MW
2x 1000MW
2x 600MW
2x 1000MW

basin
name

資料241

Specification of ‘typical’ new plant in region
Based on details of plants under construction in a number of
economies in the region, the typical features include:
–

–
–
–
–
–
–
–

Greenfield site: 2 units
Unit size: 600MW
Steam conditions 24MPa / 566ºC/566ºC (supercritical)
Boiler draft (PA, FD & ID): 2 fans for each system
Wet cooling
Wet limestone flue gas desulphurisation
Selective catalytic reduction DeNOx
Coal: high rank bituminous

資料242

Layout of ‘typical’
new plant in region

Generic layout:
2 x 600MW
coal fired plant

資料243

Assumptions for future retrofit of CO2 capture
•
•
•
•
•

Chemical absorption CO2 scrubbing technology will be used
Solvent may be amine, ammonia or ‘designer’
Worst case solvent regeneration energy requirement
The CO2 compressors will be steam driven
The plant will already be designed for FGD & DeNOx

資料244

Modifications necessary for ‘capture ready’
Essential

Desirable– Plant location– Flue gas system– Plant space / layout– Steam system– Water / steam condensate
systems– Cooling water system– Balance of plant

資料245

Modifications necessary for ‘capture ready’
Level of preinvestment
LOW

MEDIUM

HIGH

Required plant modifications• Identification of storage options• Allocation of space for additional equipment: CO2
scrubber, regenerator, compressor; auxiliary boiler• Identification of storage options• Turbine steam piping mods for future take-off• Allocation of space for additional equipment: CO2
scrubber, regenerator, compressor• Identification of storage options• Over-sized boiler for future steam take-off• Allocation of space for additional equipment: CO2
scrubber, regenerator, compressor

資料246

Modifications necessary for ‘capture ready’
Lowest pre-investment option:• Minimum modifications so as not to preclude future retrofit• Allow for future capture of 50% of CO2• Layout designed to minimise flue gas duct lengths andsteam supply distances• Area allowance for future auxiliary boiler, CO2 scrubber,stripper and CO2 compressor

資料247

Conceptual layout: low
pre-investment option(future 50% CO2
capture)

資料248

Modifications necessary for ‘capture ready’High pre-investment option:• Optimal modifications to minimise cost of future retrofit• Allow for future capture of 100% of CO2• Layout designed to minimise flue gas duct lengths andsteam supply distances• Larger boiler to provide stripper steam requirements
without plant de-rating• Area allowance for CO2 scrubber, stripper and CO2compressor

資料249

Conceptual layout:high pre-investment
option (future 100%
CO2 capture)

資料250

Conclusions• There is a need for a universal definition of capture ready• The degree of capture readiness needs to be tailored toeconomy and utility requirements• It is expected that for developing economies it will be
desirable to have low pre-investment capture ready designs

資料251

Future work on APEC project• Case study potential in other developing APEC economies• Cost estimates• Technical guidelines• Final report

資料252

2009 APEC Clean Fossil Energy
Technical and Policy Seminar
Sogondo Convesia, Incheon, Korea

CCS Policy and Development
Status in Japan
Oct. 12, 2009
Masato Takagi
Research Institute of Innovative
Technology for the Earth (RITE)

資料253

1

Overview of RITE
 What is RITE ?
RITE (Research Institute of Innovative Technology for the Earth) was establishedin July 1990 as an international center of excellence which would work toward
implementing the plans on: Development of Innovative Environmental Technologies
 Expansion of CO2 Sinks
 RITE Activities:
 Injecting 10,000 tons CO2 in Japan from 2003 to 2005 to demonstrate thegeological storage technology.
 Developing innovative CO2 scrubbing solvent and membranes for CCS.
 Producing valuable chemicals such as ethanol etc. from biomass.
 Conducting systematic studies regarding policies and measures for
mitigation of global warming. For example “Sector approach”
 Fundamental Property:
Approx. US$ 100 million
 Location: Kansai Science City, Kyoto
 Staffs: Dr. Yoichi Kaya, Director-General17- 豪州関係
Approx. 160 (including approx. 120資料254
researchers)2

Contents
1.CCS Policy in Japan
2. Capture Technology Development
3. Geological Storage Activities
4. Study for a Large-scale Demonstration
5. International Cooperation
資料255

3

1. CCS Policy Cool Earth 50 (May 2007)

A long-term objective to "reduce global greenhouse gas emissions by half compared to the current levelby 2050.“ was proposed Cool Earth-- Innovative Energy Technology Program (March2008)
21 technologies that can contribute to substantial reductions in carbon dioxide emissions by efficiency
improvements and low carbonization were selected Action Plan for Achieving a Low-carbon Society (July 29,
2008)
Japan will promote the development of CCS technology with the target of the cost of capture in theorder of 2,000 yen per ton by around 2015, falling to 1,000 yen or so in the 2020s. At the same time,
Japan will commence verification tests on a large scale at an early stage from 2009 onward, with theaim of implementation by 2020.

 Report by the Carbon Dioxide Capture and Storage (CCS)
Study Group: “For safe operation of a CCS demonstration
project” (August, 2009)
The report regarding safety and environmental standards for processes involved in CCS demonstration
projects, including geological considerations in examining candidate sites for CCS demonstration,issues related to CO2 capture and transport, monitoring items after storage, and remedies for potential
problems was released
資料256

4

1. Policy: Innovative Energy Technologies

資料257

5

1. Policy: Roadmap

CaptureStorage

資料258

6

2. Capture Technology Development
 Current Cost:– 4200 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 (KS-1, RITE solvents)– Pre Combustion: physical and chemical absorption, membrane– Oxy Fuel: Callide A

資料259

7

2. Capture Technology Development－Chemical Absorption －●Demonstration test for coal-fired●Bench scale test for Steelworks

power plant・Implementation body: RITE,
Nippon Steel Co., etc.
・Location: Kimitsu Steelworks
・Absorbent: RITE solvent
・Capacity: 1 tCO2/d
・Project period：： 2004-2008FY

・Implementation body: MHI・Location: Matsushima thermal
power Plant
・Absorvent：： KS-1・Capacity：： 10 tCO2/d
・Project period：： 2006FY-

Next test :Next pilot test: 30t/d

100-500t/d →3000t/d
資料260

8

2. Capture Technology Development－New Chemical Absorption Solvent －Regeneration energy [-]RITE developed new chemical absorption solvents with low
energy consumption.

Aspen-plus energy estimation based on the data in 1 tCO2/day mini-plantshows around 2.5 GJ/tCO2 for regeneration energy of CO2 in 3,000
tCO2/day scaled capture plant.
This solvent is now being tested in 3 tCO2/day plant for a power plant inAustralia and will be tested in 30 tCO2/day plant for a blast furnace by 2010.
資料261

9

2. Capture Technology Development－ Membrane －

資料262

10

3. Geological Storage Activities
 Storage Capacity Estimation:• Many aquifers and some depleted oil/gas reservoirs were
investigated for a CO2 storage reservoir.
– Anticline: 30 billion– Geologic structure without anticline:116 billion

 Nagaoka Project• 10,000 tons of CO2 were injected into a deep saline aquifer andvarious kinds of monitoring were applied for identifying CO2
migration and distribution.

 Large Scale Demonstrations• Japan will commence verification tests on a large scale at an
early stage from 2009 onward, with the aim of implementation by
2020.
<Action Plan for Achieving a Low-carbon Society, 2008 >
資料263

11

3. 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.

資料264

12

3.CO2 Geological Storage -Nagaoka ProjectInjection well

Nagaoka Site

Nagaoka city
Tokyo
RITE (Kyoto)

Hiroshima
CO2 storage tank

1000m
2000m

CO2 injection pump
Evaporator

5000m

Target depth 1100 m
Gas production from 4500 m depth

CO2 injection well
資料265

13

Nagaoka Project[Pilot test overview][Well configuration]

CO2 injection period

Jul. 2003 to Jan. 2005

CO2 injected amountabout 10,400 t-CO2

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
Logging

120 m

Observation well 2
40 m
Logging

Injection well 1
mographyseismic to
ll
e
w
s
s
ro
C

[Outline of injection experiment ]CO2 storage tankTransport
Evaporato
tanker lorryr
Pump

Injection wellObservation wellCaｐｐ layer：：
about 140 m

Depth：：about 1,100 m

Cap rock

Saline aquifer：：
about 60 m
Saline aquifer

Injection layer ：about 12 m

CO2

CO2
資料266

Inclination ：１５°
１５°

14

jCCS

4. Study for a Large-scale Demonstration
Incorporation of JAPAN CCS Co., Ltd.
Date of Incorporation

May 26, 2008

Capital242,500,000 yen（Capital Reserves 242,500,000 yen））

Shareholders（37 companies））

11 electric power companies
5 petroleum companies
5 engineering companies
5 general trading companies
4 petroleum resource development companies
3 iron and steel companies
2 city gas companies
1 chemical company
1 nonferrous metal and cement company

Board Member（9 Directors and1 Auditor））- President and Representative Director: Shoichi Ishii(Managing Director, Japan Petroleum Exploration Co.,Ltd.)

Ongoing
Demonstration Projects
commissioned by
NEDO and METINEDO: Feasibility study on a CCS total system
METI : Evaluation study for site screening and fieldsurvey at candidate sites for CCS
demonstrations
資料267

15

jCCS

Basic Concept of NEDO Project- one of candidate sites for demonstration -•CO2 is to be captured at the Nakoso IGCC demonstration plant, transported
to the Iwaki-oki Gas Field and stored in depleted gas reservoirs in the field.
– IGCC, Integrated coal Gasification Combined Cycle, demonstration plant isowned and being operated by Clean Coal Power R&D Co., Ltd. (CCP).
– Iwaki-oki gas field was operated by Inpex.

•

Term: July 2008 – 2010
Nakoso IGCC
Offshore Pipeline

Air-blown
250MW

Iwaki-oki Gas Field
CaptureSub SeaCompletion
WD 150m

Compress

Fukushima Iwaki-oki
Gas Field

Iwaki
ca.80kmTOKYO

Nakoso
IGCC

Ibaraki

Depleted Gas Reservoir
2000mbMSL

N

資料268

16

4. Study for a Large-scale Demonstration:
Osaki Cool-Gen
 Implementation body:
Osaki CoolGen Corporation(Chugoku Electric, J-Power) Location:
Osaki Power Station,
Hiroshima
Plant Size：： 170MWSchedule：：• Construction
March 2013–• Demonstration test of
IGCC
May 2017• CCS demonstration
2021資料26917

5. International Cooperation
 Japan cooperated with Australia to proceed
Callide A project and joined GCCSI.
 Further cooperative works are exploring:• Japan-Australia Coal Policy Dialogue(Coal Technology Workshop) (June 2009)• Japan-U.S. CCS Cooperation Meeting in Washington
D.C. (July 2009)• Japan-China CCS-EOR Workshop in Beijing(September 2009)• Japan-Canada Dialogue (September 2009)

資料270

18

5.International Cooperation

資料271

19

Conclusion●Major challenges for deployment of CCS in Japan1．
．To investigate more reservoir candidates2．
．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 scale demonstration
test.

資料272

20

Thank you for your attention !

資料273

21

Overview of Canadian
Policy and Project Activities in
Carbon Capture and Storage (CCS)2009 APEC Clean Fossil Energy Technical and Policy Seminar
12-14 October 2009, Incheon, Republic of Korea
Dr. Frank Mourits, Natural Resources Canada (NRCan)
資料274

2

Presentation Overview
 Background¾ Importance of CCS¾ Opportunities and Challenges

 Overview of CCS Initiatives in Canada¾ R&D¾ Demonstration Projects¾ Collaboration with industrial, provincial andinternational partners¾ Policies and Regulation

 Conclusion
資料275

3

CCS will help Canada meet its
energy and environmental needs
 Energy production is one of the cornerstones of theCanadian economy, but leads to GHG emissions
 Challenge: reconciling an economically important energy
sector with climate change objectives
 CCS could help balance Canada’s energy,
environmental and economic goals
Total exports“Carbon capture and storage
technology holds enormous
potential to reduce our greenhousegas emissions as we use ourenergy resources to power our
economy.”$100
billionTotal Exports

Prime Minister Stephen Harper, Feb. 2009
資料276

Canada’s primaryenergy exports (oil,gas and electricity)
as proportion of
Total Exports (2008)

4

Canada has aggressive goals
for reducing GHG emissions• Committed to reduce its GHG emissions 20%
below 2006 levels by 2020 and 60-70% by 2050

290 Mt20%

Business as usual emissions

Canada’s GHG Goals*Based on most recent data - does not account for recent economic downturn
資料277

Great potential for CCS to reduce GHG
emissions in key industrial sectors

5

Canada’s Business As Usual (BAU)
GHG Emissions to 2030
1000

Oilsands
Oil & Gas

800

Electricity

These 4 sectors
account for almost
50% of Canada’s
BAU Emissions

Industrial

600

Agriculture

400

Transportation

200

Commercial
Residential
Other

20
30

20
25

20
20

20
15

20
10

20
05

20
00

19
95

0
19
90

Mt of CO2 Equivalent

1200

Environment Canada (July 2008)*Based on most recent data - does not account for recent economic downturn
資料278

CCS could lead tosignificant GHG
reductions in these
sectors
CCS in the oilsands:a unique Canadianchallenge

6

CCS is an integrated system oftechnologies . . .
CaptureVariouspossibletechnologies
and costs
for each
stepTransport• Post-combustion• Pipelines• Pre-combustion• Road• Oxy-fuel• Rail(Not
preferred)• ShipMost expensive:~$100-150+ per
tonne CO2

Up to ~
$25/tonne CO2(pipelines)

Storage• Enhanced oil
recovery• Depleted oil and gas
reservoirs• Saline aquifers• Unmineable coalseams

~ $5/tonne CO2

Capital costs for most large-scale CCS
demonstrations range from $500M - $1B+
資料279

7

. . . which are each at different
stages of development.

Market Maturity

Transport

Pipelines
Enhanced oil
recoveryStorage
Pre-combustion

CaptureDepleted oil andgas reservoirs,
saline aquifers
Unmineablecoal seams

Post-combustion

Capturetechnologies
require themostdevelopment

Oxy-fuel

R&D

Demonstration

Commercialization

Technology Maturity
資料280

Maturetechnology

8Canada has a natural CCS
advantage…
Sources

Sinks

Many large point sources are located near potential storage sites

資料281

9

...and has already considerable
experience with CO2 injection and storage
Commercial Enhanced Oil
Recovery (EOR) – injecting CO2
Commercial acid gas injection
from natural gas processing –50+ operations, 1 Mt/yr of CO2
total
Pilot EOR – injecting CO2
Deep Saline Formation
Storage projects – early stages;some initial test wells
Pilot Enhanced Coalbed
Methane (ECBM) –completed
Major research underway toevaluate CO2 storage offshore in
Eastern Canada (Nova Scotia).

Weyburn-Midale – 2.8 Mt/yr;
also site of IEA CO2 Monitoringand Storage Project
資料282

10

...but there are numerous
challenges
 Costs
 Not yet commercially viable as an integrated
system Few large-scale demonstrations exist
 Lack of pipeline infrastructure Regulatory frameworks not yet in place Public acceptance Time pressures: new builds and capital stock
turn-over
資料283

CCS policy in Canada:an overview

11

A suite of interdependent initiatives to create theenvironment for implementing CCS

Research andDevelopment(R&D)

Collaboration with
provincial,industry, andglobal partners

Demonstration
Projects

資料284

Legislation andRegulation

12

Federal Funding for CCS
Research & Development
 Federal funding for CCS R&D - $55M
¾ Funding sources: Program of Energy Research andDevelopment (PERD); ecoENERGY Technology Initiative(ecoETI, 2007)¾ CCS research at NRCan CanmetENERGY labs
¾ IEA GHG Weyburn-Midale CO2 Monitoring and Storage
Project (2000-2011)¾ North American Carbon Storage Atlas Project (Canada,
U.S. and Mexico, 2012) Clean Energy Fund (2009): $150M for R&D¾ a portion will likely go to CCS (yet to be announced)
資料285

13

Federal funding forlarge-scale demonstrations
 Significant federal funding for large-scale demos¾ ecoENERGY Technology Initiative (ecoETI, 2007) $151M for cofunding small-scale field trials and essential
pre-demonstration engineering work (FEED studies),
which will lead to large-scale demonstrations¾ Budget 2008
 $240M for Boundary Dam Project (amine capture from
100 MW rebuilt coal-fired boiler, followed by EOR)
 $1.3 billion government-industry partnership one of the world’s first and largest integrated CCS projects
at a coal-fired power plant (1 Mt/yr by 2015)¾ Clean Energy Fund (2009) $650M for clean energy demos, primarily large-scale CCS
資料286

14

Locations of CCS projects fundedby ecoETI program
Fort Nelson Exploratory Project(Spectra Energy Transmission)

Heartland Area Redwater Project(ARC Resources)

Alberta Saline Aquifer Project(Enbridge)

Integrated Carbon Capture and Enhanced
Oil Recovery (Enhance Energy)

Pioneer Project(TransAlta)

CO2 Injection in Heavy Oil Reservoirs(Husky Energy Inc.)• Genesee Post-Combustion
Demo Plant• IGCC power plant (Capitol
Power, formerly EPCOR)

Belle Plaine Integrated
Polygeneration CCS
Project (TransCanada)
IEA Weyburn-Midale
Monitoring and Storage
Project

Saline Aquifer
Enhance Oil Recovery

資料287

15

Clean Energy Fund

 Announced in Budget 2009 ($1 billion over 5 years)
 Co-funding (public-private) initiative; focus on collaboration
 3 Components:¾ Large Scale CCS Demonstration Projects ($650M)- to support 2-3 projects that are at/near full commercial scale- Announced last week: Shell Canada $1.35 billion Quest
Project (Scotford oilsands upgrader near Edmonton, Alberta).
Federal Gvt: $120 million; Alberta: $745 million¾ Research and Development ($150M)- Four targeted areas, incl. CCS. Details to be announced¾ Demonstration projects in renewable energy and clean
energy systems ($200M)
資料288

Provincial Funding of CCS Research,
Development and Demonstration
 Alberta¾ $2 billion fund to encourage construction oflarge-scale CCS projects to reduce emissions
from coal-fired electricity plants, oilsands
extraction sites and upgraders by up to 5 million
tonnes annually by 2015
¾ $159M for ………

 Saskatchewan¾ $7M towards $12M ??? Centre at University ofRegina¾ Saskatchewan-Montana Project
資料289

17

Federal collaboration with
provinces and industry
 Canada-Alberta ecoENERGY CCS Task Force¾ January 2008 report includes recommendations for industrygovernment collaboration on CCS (e.g., $2B)

 Alberta CCS Development Council¾ Appointed in April 2008; developed a CCS implementation planfor Alberta; final report released in July 2009

 Council of Energy Ministers (CEM)¾ Established Canadian CCS government-based Network (June2009) to coordinate and accelerate CCS in Canada SaskPower (Boundary Dam Project) - $240M (2008)
 Nova Scotia Geological Research - $5M (2008)
 University of Calgary CCS Research - $5M (2008)
資料290

18

International Collaboration
 Endorsed G8 commitment to launch 20 CCS
demonstration project worldwide by 2010
¾ Canada hosts G8 in 2010

 Clean Energy Dialogue (CED) with U.S.
¾ February 2009 agreement to work collaboratively on clean energy
technology research, development and deployment, including CCS

 Legal member of the Global Carbon Capture and Storage
Institute (GCCSI) in Australia¾ Global centre of expertise for accelerating deployment of CCS
demonstration projects worldwide ($100M per annum) Participates in International Fora
¾ International Energy Agency (IEA); Carbon Sequestration Leadership
Forum (CSLF); Asia Pacific Partnership (APP); Asia Pacific Economic
Cooperation (APEC)
資料291

19

Federal GHG reduction
regulations
 Canada committed to reduce its GHG emissions 20%
below 2006 levels by 2020 and 60-70% by 2050
 Also driven by commitment to achieve 90% of electricity
from non-GHG emitting sources by 2020
 Significant regulatory work underway by Environment
Canada, leading up to COP15 (Copenhagen, Dec. 2009) Policy framework being developed will focus onproviding incentives for technologies like CCS
 A Technology Fund will likely be created as a complianceoption
資料292

Conclusion

20

 CCS is of great strategic importance to Canada There are a number of challenges associated with
CCS implementation
 Total of $3.3 billion currently being allocated inpublic funding from federal and Alberta
governments for large demonstration projects
 The federal and provincial governments areworking to address these challenges through:
¾
¾
¾
¾

R&D
Collaboration
Demonstrations
Policies and Regulations
資料293

Thank you for your attention!
Questions?
Frank Mourits
Natural Resources Canada
fmourits@nrcan.gc.ca

資料294

APPENDIX
Details of Projects Funded byecoENERGY Technology Initiative
(ETI)

資料295

23



ecoETI projects:
saline aquifer storage
ARC Resources Heartland Area Redwater Project (HARP)
CO2 capture from one or multiple industrial sources in Alberta’s
Industrial Heartland, NE of Edmonton, and injection into thecarbonate Redwater Leduc reef (several million tonnes per year)TransAlta Pioneer / Wabamum Area Sequestration Project(WSAP)
post-combustion (chilled ammonia) capture of 1 Mt/y CO2 from the
Keephills coal-fired power plant in the Wabamun Lake area SE of
Edmonton, and injection into Nisku Formation carbonates as well as
CO2-EOR

Capital Power Genesee Project and Enbridge Alberta Saline
Aquifer Project (ASAP)
post-combustion CO2 capture from a new IGCC coal-fired power
plant (1 Mt/y) and injection into Nisku Formation carbonate aquifer
SE of Edmonton
資料296

24

ecoETI projects:
saline aquifer storage (cont’d) Spectra Energy Fort Nelson project
capture of 1.2 to 2 Mt CO2 with H2S from Spectra’s
Fort Nelson gas plant in NE B.C., and injection into
Keg River Formation carbonate aquifer-------------------------------------------------------------------The following project is not funded by ecoETI, but receives federal funds
from Sustainable Development Technology Canada: Aquistore project
capture of CO2 from the COOP refinery in Regina,
Saskatchewan, and injection into a deep aquifer in
the Williston basin (aquifer storage)

資料297

25

ecoETI projects: CO2-EOR

 Enhance Energy / Northwest project
capture of CO2 from bitumen upgrader(s) and fertilizer plants inAlberta’s Industrial Heartland NE of Edmonton, and storage in CO2EOR operations, including construction of a CO2 pipeline (~2 Mt/yincreasing to 15 Mt/y) Husky Lloydminster project
capture of CO2 from Husky’s heavy-oil upgrader and ethanol plant andstorage into heavy oil reservoirs in the Lloydminster area (300 kt/y) TransCanada Polygeneration projectengineering and design work for a polygeneration plant in Belle
Plaine, Saskatchewan, which will gasify petcoke to produce electricity,hydrogen, steam and sulphur. Captured CO2 to be used for CO2-EOR
or stored in saline aquifers
資料298

Cleaner Coal: Moving Towards Zero Emissions
2009 APEC Clean Fossil Energy Technical and Policy
SeminarStatus of Oxy-Fuel Combustion Projectin Korea

2009. 10. 12

Sung -Chul Kim
Korea Electric Power Corporation
Korea Electric 資料299
Power Research Institute1. Status of CO2 Emission in Korea
2. Introduction of Korean Oxy-combustion Project

3. Summary of Korean Oxy-combustion Project

資料300

(CO2 Emission Trend )[Energy Sector]

Unit : million-ton CO2
EnergyIndustry

Agriculture, Waste

453.2

531.0

2.1%

599.5

Home,
Commerce
12.3%

298.1

Transport.
19.7%
84.3%

Industry
35.4%

83.1%
6.7%
10.2%

1990

10.6%
5.1%

1995

2000

Etc.

2006

CO2 Emission in 2006 : 599.5 million-ton (9th in the World)
98% Increase versus 1990’s
Energy & Industry Sector → 95% Share of Total
資料301

Power
Gen.
30.5%

( CO2 Emission Trend)

Share of Power Sector (%)
Unit : million Ton

17.0%

22.0%

20.3%

24.0%

12.0%

CO2 Emission in Power Sector : 154 million Ton (2006)
Increase of Approx. 4.3 Times versus 1990’s
Power Sector’s Share : 12.0% (1990) → 25.7% (2006)
資料302

25.7%

Scenarios of CO2 Reduction Target in Korea(2009, August, BAU)
( Unit: Mil.Ton CO2 )Scenario 1
Scenario 2
Scenario 3

資料303

The Present State of Green House Gas in Korea
Korea is expected to be the obligatory reduction country by Kyoto Protocol during 2nd
commitment period; 2013-2018
Actual technology needed to correspond with the state of obligatory reduction

84% CO2 from Electric Power
Generation

State of C02 Emission in Korea
 CO2 : 590 mil-tonCO2/yr(2006)

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

 Coal firing power plant : 154 Mil-tonCO2/yr• 26% of total CO2 emission• 75% of total power generation• In case of including Heavy oil, Max. 84

Ideal target for Apply CCS Technology
CO2 Capture & Storage

資料304

Summary of the Progress for
Korean Oxy-PC Project Oxy-Fuel Combustion R&D~

Started in 2002 for Oxy-NG Combustion for Industrial Furnace~

Small Scale Oxy-Coal Combustion R&D from 2006 by CDRS(KIER)

 MKE(Ministry of Knowledge Economy) : Energy R&D Program~~

10 New Researches are Proposed (2006)
Planning Report submitted : May 2007

 National R&D Program Led by KEPRI~~

Launched in October 2007
Industrial Participants
~
~
~

~

KOSEP
Dae-sung Industrial Gas
Korea Cottrell

Tentative Demonstration Site : Young-dong Power Station Unit #1

資料305

Korean Project on Oxy-coal Combustion First step of a long term project aiming 2020 and beyond Finding solution in the CCS~~

Design development of oxy-coal power plant
Coal power plant as highly visible point source (320 M tCO2/y @ 500MW
unit)

 Demonstration of Carbon Capture and Storage Readiness for coal
fired power plants by 2018(100 MW)
 Technical Significance~~Commercial-scale oxy-coal plant (~500MW)
Cost of CCS <30€/tCO2

資料306

Plan of Research and Development for Oxy-PC Combustion
Phased Target
3rd Step
1st Step’07.10~’10.09(3yrs)

Development of conceptual Design
Of Oxy-PC combustor

2nd Step’10.10~’12.09(2yrs)

Basic Design of
Oxy-PC power plant-Conceptual Design of Oxy-PC Boiler-Optimization & Integration of
Oxy-PC Boiler-Basic Design of Oxy-PC Plant-Pilot plant test operation-Development of key
technology of Oxy-PC Combustor-Development of SOx & Dust
Removal New Technology-Preparation of construction-Development of key technology

資料307’12.10~’05.09(3yrs)

Detailed Design & Construction of
100MW grade Oxy-PC Power plant

Detailed Design &Construction of
Demo. Plant(100MW class)Oxy-PC Technology Development Plan

Phase I (2007~’10)
Research andConceptual Design
Development

Phase II (2010~’13)
Basic/Detailed
Design of a Demo.
Plant

Phase III (2013~’15)
Construction of
Demo. Plant

Plant Conceptual
DesignBoiler &Combustion

Environmental
Control

KEPRI

KEPRI/KITECH

KIMM

KOSEP
Dae-sung Ind. Gas

Boiler & Burner

Optimum Operation

Development

KIGAM

KOSEP

KOSEP

Design Concept for

CO2 Storage

Korea Cottrell

Flue Gas Cleaning for
Plant Maintenance
資料308

Fundamental Study
CSLF : Otway Bay
ProjectOptimization Technology

Development of Oxy-PC Power Gen. System Optimization Technology
FinalTarget(ASU-Boiler-FGR-CO2 recovery]

Drawing of Oxy-PC Power Gen. System Concept Design(Efficiency Penalty under 8% )AnnualResearch
TargetYe2ar2 1

Establishment of process analysis method for Oxy-PC Power Gen. System

Year 2

Deduction of integrated process analysis & system integration method
for Oxy-PC Power Gen. System

Year 3

Deduction of the optimum concept design for Oxy-PC Power Gen. System

Expected effectEnsuring technology independence & essential technologyof Oxy-PC Power Gen. System
資料309

Conceptual Design of Oxy-PC Boiler
100MW Class Oxy-PC Boiler
Conceptual Design
Infra. for Oxy-PC Boiler Design
PC Boiler Design Tech.
Oxy-PC Boiler
Conceptual Design
Oxy-PC Boiler Design Infra.
PC Boiier Design Guidelines
PC Boiler Design ProcedureOxy-PC Boiler Combustion Test

Oxy-PC Furnace Design
Oxy-PC Tube Bank Design

Oxy-PC Boiler Design Procedure Heat & Mass Balance DesignSmall Scale Oxy-PC Boiler Test
Oxy-PC Boiler Design ToolPerformance Characteristics

1st Year

2nd Year

資料310

3rd YearOxy fuel Development Strategy
To develop a competitive oxy-fuel firing technology suitable for full plant
application post-2015• A phased approach to the development and demonstration of oxy fuel technology• Phase 1:– Fundamentals
Technologies andconceptual Design• Phase 3:• Phase 2:– Basic Design of Oxy fuelCombustion System

資料311– Detail Design andRepowering of 100MWeclass power plant13

Oxy-PC Facility Schematic Diagram

Gas + P.C

Pulverized Coal Firing

資料312

ASU Facility

Air
Tank
Comp.
Warm
Part

Cold
Box

資料313

Proposed Demonstration Project
CO2 Capture

Repowering the Young-dong unit #1~~~

Current : 125MWe . Domestic Anthracite
Decommission by 2013
Repowering to Oxy-Fuel Boiler~100MWe Class Demonstration
~
~

資料314

Coal : Imported Sub-Bituminous or Bituminous
coal~

Design by 2013
Construction by 2015
Demonstration : 2016~2018

Simplified Oxy power plant in Young Don

ASU
Ash Pond
Coal
Yard
FGD
ESP

CO2 Processing

Boiler

Turbine House

資料315

Actual power plant design condition

ITEM

Summary (Yungdong#1)

Capacity

125MW

Fuel

Anthracite, bituminous
coal, heavy oil mixing

Main Stm.
Pr/Temp131.9 kg/cm2 / 541C

Efficiency

36%

Comp. Year&
manufacturer

1973, HITACHI

資料316

Design Boiler

Type : Subcritical, drum type, 1 Stage reheat,balanced Draft, constant pressure
Capacity : 420 T/H (MCR)
Fuel : Sub-Bituminous, coal light oil (start up)
STM Cond. (S/H out) : 131kg/cm2, 541℃
(R/H out) : 31.5kg/cm2, 541℃
Boiler efficiency : 93%
Combustion Type : Dual type(Oxy, Air Combustion)
Environmental : In-Furnace(Oxy Comb.) FGD(Air Comb.)

資料317

Young-dong Opportunity
 Young-dong Power Station~~

Unit #1 : 125MWe
Coal Type : Domestic Anthracite (Heavily Subsidized)

 Oxy-Fuel Opportunity @ Young-dong Unit #1~~

Coal Supply for unit #1 : End by 2013
MOEnv. will not Renew the Environmental Permit for the Current
Unit
~

~

New Unit is Necessary

KOSEP decided to convert the unit #1 for Oxy-Fuel option~~

Coal Type : Sub-Bituminous or Bituminous coal
Optimize the Electric Cost

資料318

Technological Objectives
 Performance Optimization~~

Control & Management of Incondensible Gas (Ar, N2, O2,)
Combustion~~

Low NOx & Excess O2 Combustion

Boiler Optimization : Capture Ready Possible

 Plant & Environmental Cost~

Bypass SCR & FGD~

Dry DeSOx Process : Combined with Low Sulfur Coal Type & Hybrid EP

 CO2 Treatment~~

Currently No Full Scale CO2 Storage Possible
Main Concern~~

Technical Issues in Post Capture Treatment (Purification & Compression)
Utilization of the Captured CO2

資料319

Summary Korea Government have a plan to join the 20 by 20 CCS Project which
will be selected on 2010 G8 Extended Summit meeting Korea Government proposed three scenarios to cut it’s C02 emission by2020 , final reduction target will be confirmed by the end of this year
through a national consensus
 KEPEI and KOSEP would like to install the Demonstration of Carbon
Capture and Storage Readiness for coal fired power plants by
2015(100MW) in Young Dong Power Plant

資料320

(5)セッション 3A

資料321

2009 APEC
Clean Fossil Energy Technical and Policy Seminar

NEDO’s Activities for
Clean Coal Technology
October 12, 2009
Clean Coal Projects Department

New Energy and Industrial Technology
Development Organization
資料322

What is NEDO ?

NEDO is Japan's largest public R&D management organization,that is established for promoting R&D activities in Japan toenhance Japan’s industrial competitiveness.
NEDO’s R&D Promotion Scheme(1) NEDO is Established by theJapanese government(2) NEDO is responsible for･ R&D project planningand budget requesting･ Project Management･ post-project evaluation andprevalence

URL： http://www.nedo.go.jp/english/index.html

資料323

Current R&D for reducing CO2 emissions
from power gen.

- Increasing efficiency of power generation- Carbon capture and storage (CCS)
from power plants
資料324

Improving Efficiency of Coal-fired Power Generation

Efficiency（％）(1) Advancement of power generation efficiency
42

In Japan, practical use of supercritical power generation (ＳＣ) & ultra
supercritical power generation technologies (USC) increased power
generation efficiency by approx. 2.5% from 1980 to 2005.

41
40

+２.５％

39
38

Power generation
capacity share（％）(2) Coal-fired power generation trends & efficiencies
100
80
60
40

PFBC

SC

USC

（efficiency:
40.1-42.7％）（efficiency:
41.5-43.0％）（efficiency:
43.0％）

C（efficiency:
37.4-40.7％)

20
0

1980

1985

1990

資料325

1995

2000

(Ratio of C to SC, and SC to USC has changed drastically)

2005

year

NEDO’s R&D projects fossil fuel processing
Hot-COG
Reforming project
EAGLE projectH2 (for chemicals, fuel cells and fuels)
Reduction ofiron ore

Hydrogenproduction

Electricity

Iron

Course 50
project

Reduction

CO+H2

Gas turbine andfuel cells

Hyper coal

FT synthesis
ATL project

Gasification

Coal refining
Gasification
simulator project

Hyper coal project

Coal

Petroleum

Hydrogenation(coal and heavy oil)

Biomass

NEDOL project
BCL project

資料326

Liquidfuels
4

Coal-fired Power Generation Technology Development(1) Present status in Japan
Efficiency of ultra supercritical power plant (USC): 40.6% (HHV) / 42.0% (LHV)(2) Power generation technology development roadmap
2010

2020

2030

Efficiency: HHV basis

2040

2050

① Coal gasification combined power generation
・IGCC project
1,200℃-class GT
Efficiency: 41%（Air-blown Nakoso
Demo. 250 MW）
・EAGLE project（IGCC, IGFC, etc.）
EAGLE pilot(Oxygen-blown
150 t/d Wakamatsu)

1,500℃-class GT
Efficiency: 46-48%
CO2 reduction: 20%
EAGLE Demo
Plant (200 MW)

1,700℃-class GT
Efficiency: 50%

IGFC
IGFC Demo plant Efficiency: 55%
CO2 reduction: 30%

Next generation IGCC
Efficiency: 57%

Next gen. IGFC＊
Efficiency: 65%
CO2 reduction: 40%② Next-generation supercritical power generation （Advanced-USC）
600℃ class
Efficiency: 41%

700℃ class
Efficiency: 46%

800℃ class
Efficiency: 48%

Reference: LNG-fired power generation
1,500℃class GT
Efficiency: 53%

1,700℃class GT
Efficiency: 56%

FC/GT combined
Efficiency: 63%
資料327＊Next generation IGFC output efficiency is expected to reach 65% by 2050. That would exceed
the 63% FC/GT efficiency LNG-fired power generation is expected to reach in 2030.

International Collaboration in CO2 Capture R&D-Basic R&D-Improvement ofAbsorbent

Next Generation Separation Technology (Membrane CO2 & Air Separation)
Gasifier

Pre-Combution(IGCC)

Gas Cleaning

Composition % :dry base

CO2 Capture
Shift Converter CO2
up to 40%

OxygenHydrogenGas Trubine

CoalCO, H2CO2, H2

Shift Conversion
CO+H2O  CO2+H2
Air

EAGLE Pilot Plant (IGCC+CO2 Capture )

ASU

H2

CO2

Low Nox
Combustion
Composition % :dry base

Post-Combution(PCC etc.)

Boiler

Gas Cleaning

CO2 Capture

CO2
12~14%

ExaustAir
Coal

Amine Absorption Technology (MHI, Toshiba, Hitachi, etc.)
Boiler

Oxy-fuel
Combution

Gas Cleaning
CO2

CO2
up to 95%

CO2

-Demonstration-Improvement ofAbsorbent

Cooling Unit

Composition % :dry base

OxygenCoal

Water
CO2 Circulation

Air

CO2

ASU
資料328
Japan – Australia Joint Demonstration
Project (Callide)Coal Gasification Technology Development(EAGLE Project)
Project Name : EAGLE
Coal Energy Application for Gas, Liquid & Electricity
Objectives
Development toward IGCC, IGFC which is combined with
Fuel Cell, GT, and ST
Development Items
STEP1(2002-2006)
1.Oxygen-blown entrained-flow gasifier
2.Gas cleanup technology for fuel cells
STEP2(2007-2009)
1.CO2 Capture Technology (without storage)- Purity of recovered CO2: 99% or greater
2.Expansion of Coal Flexibility
3.Survey on behavior of資料329
trace elements

Coal Gasification Technology Development(EAGLE Project)

Image of Gasification Furnace
Upper
Burners
(4)

H2
CO
CO2

Upper：O2 Lean
Coal→ Char
Char+CO2+H2O→CO+H2

O2

Down : O2 rich
Char+O2→CO2+H2O

Coal
CO2
H2O

Lower
Burners
(4)

gas
Slag

1200 1600

Temp. (°C)
資料330

Coal Gasification Technology Development(EAGLE Project)
Photograph of EAGLE Pilot Plant (150 tons/day)

Air separation
facilities

Incinerator

CO2 separation &recovery facilities

Gasifier(150 tons/day)Gas purifier

Sulfur recovery
facilities

Gas turbine house(8 MW)

資料331
EAGLE (Coal Energy Application for Gas, Liquid & Electricity)

Located in J-Power’s Wakamatsu Laboratory

Coal Gasification Technology Development(EAGLE Project)(Fiscal year)
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009

FS/Component test

3/2002 Charging coal

Basic design/Detailed design

3/2003 Start of operation

Fabrication/Construction

Operation(STEP-1)

Operation(STEP-2)-Large Scale Demonstration Test InitiativesProvider: Osaki CoolGen Corporation<Joint investment > the Chugoku Electric Power company and J-PowerPlant capacity :170MW classCoal feedSchedule: 1,100t/day class:- Construction FY2012 ~- Operation
FY2016 ~IGCC area

資料332

CO2 Capture area

http://www.osaki-coolgen.jp/index.html

Innovative Zero-emission Coal Gasification
Power Generation Project (1/2)
Feasibility study (on total system from power generation to CCS）
(1) Coal gasification/
Power gen. Capture/
Storage(2) Transport(3) Storage■System design
Ｈ2

TurbineGeological storage
Marine transport

CO＋Ｈ2

Coal gasification■Coal type test

CO2
＋Ｈ2

CO2
separation/
capture■Design of marinetransport system
CO2

Compressor■Research of storage
potential, cost (multiple sites)

Storage unit

Ship/Pipeline

Tank

ポンプ＆気化器■Chemical
absorption
methodBasic technology
・Next-generation IGCC technology with CO2 recovery (effective use of CO2)
資料333
・Hydrogen gas-turbine technology development

Innovative Zero-emission Coal Gasification
Power Generation Project (2/2)
Feasibility Study of IGCC with CO2 Storage

CCS storage: Nakoso－Iwaki offing
CO2 separated and collected from Nakoso IGCC plant willbe transported through a pipeline and stored in a depleted
natural gas field (Iwaki gas field) 70 km from Nakoso.
IGCC

Iwaki gas
field
70 km

Coal-fired
power plant
SEA

CO2
separation& capture

Fukushima
Prefecture
Iwaki City
NakosoPipeline

Gas supply lineN

Sea well device(depth: 150m)

Pressurization

Gas layer
Gas layer depth: 2,000m
資料334

Depleted gas field

12Reference
Overview of Nakoso IGCC Demonstration Plant● Summary・ Combined-cycle IGCC (Gas turbine + Steam turbine)・ Air-blown IGCC
● Specifications
Power

250 MW

Use ofcoal
Targetefficiency

1,700
tons/daynet

Gasifier
Method42%

Gas
treatmentGasturbineAir-blown dry feed
gasification
Wet gas treatment (MDEA)＋gypsum collection
1200℃● Progress
Construction began in September 2004 and demonstrative testing
started in September 2007 and will be carried out through 2009.
*Demo plant in Iwaki City,
Fukushima Prefecture＊NEDO is not involved in this project.

資料335

Coal Refining Technology
Hyper Coal Production Project (1/3)
Hyper coal technology can produce ash less coal (less than 200ppm)
HyperCoal

The image of mechanism on Hyper Coal production
SolublematterHyper Coal

Ash

Solid/Liquid
separation
Solvent recovery

Heating
Insoluble
matterCoal

Solvent

Insoluble Coal
(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.
資料336

After extraction, thesolubles (Hyper Coal)and residue(insolubles & ash) are
separated.

Coal Refining Technology
Hyper Coal Production Project (2/3)
Schedule of Hyper Coal Project2000
Production
Stage

2005

2010

2015

2020

Establishment Demonstrationof Production Commercialization
Tech.
5000t/d
100 t/dIron or non-ferrous metal smelting(Substitute of caking coal & Slag reduction)

Applicationof Hyper Coal

Pulverized coal-fired power(Coal ash reduction, CO2
reduction( ～10％))

Gas turbine c/c power generation
Research & Development
Commercialization(Efficiency 48% (1,350C GTCC),
CO2 reduction(～20％), Coal ash reduction, )資料337

Coal Refining Technology
Hyper Coal Production Project (3/3)
Production and Utilization Flow of Hyper Coal
Solvent
Extract

Coal

Solvent
Extraction(DeAshing)360 ～ 380 ℃
1MPa

Mine-Mouth Power Plant

Ion
Exchange(DeAlkalization)

Byproduct

Hyper
Coal

Insoluble
Coal

Coal
producing country
資料338

Utilizationin JapanJapanReforming Technology for Hot-COG (1/3)
In coke ovens, coke oven gas (COG) is
produced as a by-product. To avoid theunfavorable deposition of tar, the sensible
heat is not effectively used.
Aims of the project :reforming of tar with sensible heat of COG(1) Improving efficiency(2) Product syngas can be used for Clean fuelProduction, such as Hydrogen, Methanol and
DME(3) Contribute to the reduction of CO2
emission and energy saving.
< This project is started in 2006 FY >Dry Main
80 ℃

COG

Coke
Oven

Cokes
資料339

Fuel for Coke Oven

COG
Tank

Reforming Technology for Hot-COG (2/3)
COG
Reforming
Technology

Off GasMethanol
Conveter

Coal

Existing or Newly Developed Process

Desulfurization

COG
Reformer

Process for
Liquid Fuel
Existing
Process

HydrogenSeparation（PSA)

MethanolPurification

Hydrogen

Dust

Methanol
DME
Conversion

Hot Collecting Main
600 ～ 700 ℃

Dry Main

Cokes

80 ℃

Coke
Oven

COG
Purification
Separation

DME

COG
Tar,Diesel Oil
Liquid Ammonia
H2SO4

Fuel for Coke Oven

COG
Tank

In-house Use

Existing Facilities
資料340

Reforming Technology for Hot-COG (3/3)

Reforming Gas Cooler

Drain
Cooling
Water

Cooling
Water

O2

M

Spray
Tower

Reformer

TE

M
TE

TE

Drain

Solid Waste

Sampling Gas

Sampling Gas

Extraction Pipe

M

Ar
Ａ DamperExhaust Gas
Sampling Gas

Coking Chamber
Hot Crude COG：600～700℃
資料341

Suction Brower

Innovative Steelmaking Technology
Development (Course50)
1) Technology development to reduce CO2 emissions from blast furnaces
2) Technology development to separate and recover CO2

2) Development of technology to separate and recover CO2

1) Development of technology to reduce CO2 emissions from blast furnaces
Reduced coke consumption

Iron ore preliminary
reductiontechnology

Other projectCO-rich gas

Coke ovenBlast
furnace

High-strength and high-reactivity coke

Technology to manufacture cokesubstitute reduction material

Sensible heat recovery technology for slag
(Example)
Hot blast
Slag

Blast furnace gas (BFG)

Coke

Cold blast

COTechnology to control reaction
in hydrogen reduction blast
furnace

CO2

Regeneration tower

HydrogenTechnology to manufacture coke forhydrogen-reduction blast furnaces

Absorption tower

COG reforming system

Shaft furnace or other furnace

Hydrogenincrease

CO2 storage technology

Iron ore• Chemical absorption method• Physical absorption method

Reboiler

CO2 separation andrecovery technology

Waste heat recovery boiler
Steam
Kalina-cycle power
generation system

Electric power
資料342

Technology to effectively use unutilized waste heat

Pig iron
Converter

Conclusion
 What should we, engineers and researchers that relatewith coal, do for the future and for our next generation in
the area of clean coal technology?
 Precious coal resource should be used efficiently.
 Our answer is ‘improving efficiency’ Based on the concept, we are developing innovative CCTtechnologies.
[ EAGLE , Hyper-coal, Reforming of hot-COG ] Furthermore, “CCS-Ready” is becoming standard forcoal fired power-plant, it is likely to be restricted also inJapan. ‘correspondence to tightening regulations’[Innovative Zero-emission Coal Gasification
Power Generation ]資料343

Thank you foryour attention!

資料344

Manabu Hirata
hiratamnb@nedo.go.jp

1

Introduction to Korea
IGCC Development Program
Dr. Ahn, Dal-HongKorea IGCC RDD&D Organization

資料345

2

Korea IGCC Development Program

IGCC Overview
 Integrated Gasification Combined Cycle (IGCC)- Power plant combining a Gasification system with a CC
- Coal is converted into a raw synthesis gas (syngas),
mostly CO and H2, in a gasification system. The raw syngas
is cleaned and then used to produce electricity in a CC
power plant Features- High efficiency: current 39~42% (HHV, Net)
• Up to 45~46% with advanced GT- Environment friendly : SOx 99.9%, NOx 25ppm- CCS ready : 90% of CO2- Flexible feedstock : Coal, Biomass, Waste, Oil Residue
 Disadvantages- High capital cost, Complex configuration
資料346

Korea IGCC RDD&D Organization

3

Korea IGCC Development Program

IGCC

Source: NETL
資料347

Korea IGCC RDD&D Organization

4

Korea IGCC Development Program

Entrained Gasifier Types
GE

E-gas

Shell

Single-stage,
Downward,
Slurry feed,
Oxygen blown,
Refractory lining,
Radiant & Quench

Two-stage,
Upward,Slurry feed,
Oxygen blown,
Refractory lining,
Fire-tube boiler

Single-stage,
Upward,Dry feed,
Oxygen blown,
Membrane wall,
Water-tube boiler

資料348

Korea IGCC RDD&D Organization

5

Korea IGCC Development Program

World Operating IGCC Plants
Plant

Year

Output (MW)Feedstock

Technology

Buggenum

1994

253

Coal/Biomass

Shell (SCGP)

Wabash1995

262

Coal/Petcoke

E-gas

Polk

1996

250

Coal/Petcoke

GE

Vresova

1996

350

LigniteLurgi (26)

Schwarze Pumpe

1996

40

Lignite/Waste

GSP

Pernis1997

120

Vis. Residue

Shell(SGP)

Puertollano

1998

300

Coal/ Petcoke

Prenflo

Schwarze Pumpe

1999

75

Lignite/Waste

BGL

ISAB Energy

2000

512

Asphalt

GE

Sarlux2001

551

Vis. Residue

GE

Chawan2001

173

Residual OilGE

API Energia

2002

287

Vis. Residue

GE

Delaware

2003

160

Fluid Petcoke

GE

Negishi

2003

342

Vac. Residue

GE

Agip

2006

250

Visbreaker Residue

Shell(SGP)

Nakoso2007

250

Coal/PRB

MHI

資料349

Source : GTC, World Gasification Database , 2008
Korea IGCC RDD&D Organization

6

Korea IGCC Development Program

Coal-based IGCC Demonstration Plant

Polk 250MW, US

Wabash 252MW, US

Buggenum 250MW, The Netherlands

Puertollano 300MW, Spain
資料350

Korea IGCC RDD&D Organization

7

Korea IGCC Development Program

Korea IGCC RDD&D Organization
 Background- Achieve government policy goal of increasing new andrenewable energy use in electric power generation fromcurrent 2.5% up to 7% by 2011
- Achieve “Korea Electric Power Development Basic
Plant”’s goal of constructing 300MW IGCC plant by 2012
 Establishment- Established in Dec 2006 in order to facilitate theresearch, development, demonstration and deployment of
IGCC program under the support of Ministry of Knowledge
Economy(MKE) and Korea New & Renewable Energy Center(KNREC)

資料351

Korea IGCC RDD&D Organization

8

Korea IGCC Development Program

Overview of Korea IGCC Program
Title

Design and Construction of 300MW IGCC Demo Plant
for the Development of Korea IGCC technology

Consortium
Partners• Prime Contractor :• Korea Electric Power Corporation (KEPCO)• Sub Contractor :• Korea Western Power, Doosan Heavy Industries• Institutes (KIER, IAE)
• Universities (Seoul, KAIST, …)Period• 2006.12.1 ~ 2014.11.30 (8 years)

Funding• Government : ~30%
• Participant : ~70%
資料352

Korea IGCC RDD&D Organization

9

Korea IGCC Development Program

Organization of Korea IGCC Program
Ministry of Knowledge Economy(Korea Institute of Energy Technology Evaluation and Planning)

Korea IGCC RDD&D Organization

1st Sub Project

2nd Sub Project

DoosanWestern Power

KEPRI

KEPRI

Construction of
300MW IGCC Plant

Development of
Operationtechnology for
300MW IGCC Plant

Development ofGasification Test
Bed & Unit
Processes

Integrated Designof Gasification
Plant

3rd

Steering Committee& Secretariat

Sub Project

4th

Sub Project

資料353

Korea IGCC RDD&D Organization

10

Korea IGCC Development Program

Objective of Korea IGCC Program
Ultimate Goal
• Acquire world class IGCC technology

Plant Efficiency (%)• Thermal Efficiency: 42%(HHV, Net)
Quantitative• NOx:
less thanGoal
30 ppm,• SOx: less than 15 ppm• Localization of Engineering
Design : >90%
• Localization of Facility
Manufacture : >90%

42.0

41.4
40.3

39.7
37.5

Tampa
(1996)

Wabash(1995)

Buggenum(1994)

Japan(2007)

Korea(2012)

Construction of World Best IGCC Plant
資料354

Korea IGCC RDD&D Organization

11

Korea IGCC Development Program

Phase Description of Korea IGCC Program
Phase 3Phase 2Phase I
’06.12~’09.11(3Yr)
Design• Environmental Impact
Assessment• Gasifier Process
Licensor Contract• Design of 300MW
IGCC Plant’09.12~’12.11(3Yr)
Construction• Procurement of Major
Equipment• Construction andCommissioning of
300MW IGCC Plant’12.12~’14.11(2Yr)
Demo. Operation• Demonstration
Operation of
300MW IGCC Plant• Performance
Improvement

資料355

Korea IGCC RDD&D Organization

12

Korea IGCC Development Program

1st Sub
Project

Integrated design of 300MW gasification plant based on
self-reliant development

Contractor• Prime : Doosan Heavy Industries• Sub : Universities(KAIST, Yonsei)

Project
Goals• Achieve the overall know-how of gasification plantengineering• Self-reliant development in gasification process engineering
Gasification Plant Engineering

Feed Preparation

Exhaust Gas Cleaning

Gasifier/Syngas Cooler
Integrated
Design

資料356

Korea IGCC RDD&D Organization

13

Korea IGCC Development Program

2nd Sub
Project

Development of engineering, manufacturing, andconstruction technology for the 300MW IGCC demo plant

Contractor• Prime : Korea Western Power

Project
Goals• Successful Construction of the most competitive IGCC plantin the world and operation of plant successfully

Seoul

IGCC
Site
Taean

資料357

Korea IGCC RDD&D Organization

14

Korea IGCC Development Program

3rd Sub
Project

Development of operation technology for Korea 300MW
Class IGCC Plant

Contractor• Prime : Korea Electric Power Research Institute (KEPRI)• Sub : Universities(Seoul, Hanyang, Inha, Hanbat, Kunsan)

Project
Goals• To enhance the availability and reliability of the IGCC plant
9 coal-gas combustion optimization technology
9 IGCC plant operation monitoring system
9 operator training simulator

ASU
14%
Gasifier
23%

Combined
Cycle
56%

Clean-up
7%

Forced Outage by Facility

Coal-Gas Combustion Test

Operator Training Simulator

資料358

Korea IGCC RDD&D Organization

15

Korea IGCC Development Program

4th Sub
Project

Development of a gasification test bed and unit
processes by domestic technology for the Korea 300MW
IGCC plant

Contractor• Prime : Korea Electric Power Research Institute (KEPRI)• Sub : KIER, IAE, and Universities(Ajou, Hongik, Suwon,
Gyoungsang)

Project
Goals• Construction and running of the gasification test bed (max. 3
0TPD)• Development of domestic design technology of gasifier parts

Gasification Facilities(KEPRI, IAE,
KIER)

Gasification Test Bed
資料359

Korea IGCC RDD&D Organization

16

Korea IGCC Development Program

Benefits: Establishment of self-reliant
IGCC technology
Basic & Detail Design for 300MW Gasification Plant

Gasification/Cleanup Process Design

Gasifier Manufacture

資料360

Korea IGCC RDD&D Organization

17

Korea IGCC Development Program

Benefits: Localization of Facility
Manufacture (more than 90%)
Sulfur Recovery

COS Removal

ASU
Gasifier
internal

Dust Removal

H2S Absorber

資料361

Gas Cooler

Dust
KoreaFilter
IGCC RDD&D Organization

18

Korea IGCC Development Program

Timeline of Korea #1 IGCC Plant
Phase I
(design)

Phase
Year

Power
Block

2007

2008

Phase II(construction)
2009

Environmental
ImpactAssessment
5

2010
Excavation

10

2012

2013

6

11

Installation oftheMain equipment

Demo.
Operation(2 year)Installation of
Gasification
Block
10

6

Contract ofLicensor

2014

Completion

6

Establishing
Project
Charter

Gasificati
on
Block

2011

Phase III
(operation)

7

Start-up
資料362

Korea IGCC RDD&D Organization

19

Korea IGCC Development Program

Conclusions- IGCC is a efficient & environmentally friendly
and lowest-option to Carbon Capturecoal-based power generation method.
- To achieve government policy goals of increasing
new and renewable energy use in electric power generationfrom current 2.5% up to 7% by 2011 and constructing 300MW
IGCC plant by 2012, Korea IGCC project has been launched.
- IGCC is highly expected to be a new growth engine in Korea.

資料363

Korea IGCC RDD&D Organization

20

Korea IGCC Development Program

Thank you
資料364

Korea IGCC RDD&D Organization

(6)セッション 3B

資料365

2009 APEC Clean Fossil Energy Technical and Policy Seminar“Cleaner Coal: Moving towards Zero Emissions”
October 12-14, 2009 Songdo Convesia, Inchon, Korea

Coal Demand/Supply Outlook in Thailand
Viroj Sivavong
Chief of Fuel Development and Planning Department
Electricity Generating Authority of Thailand

Electricity Generating Authority of Thailand

資料366

1

Thailand’s Proven Coal Reserves
|

)

Nan
Nan

|

Na
Na Klang
Klang

Tak
Tak

17ｰ

|

)

Na
Na Duang
Duang

Loei
Loei )Mae
Mae Than
Than

15ｰ

Mae
Mae Tuen
Tuen

|

)

NakhonNakhon Ratchasima
Ratchasima

Bangkok
Bangkok.

Most of the domestically produced
coal is of rather low quality, giving
low calorific value.
Thailand’s coal proven reserves haveabout 1,372 million tons

Buri
SuphanSuphanSuphan Buri|

Nong
Nong Ya
Ya Plong
Plong

|

)

13ｰ

|

|

|

Mae
Mae Lamao
Lamao

13ｰ

19ｰ

Mae
Mae Teep
Teep
Mae
Mae Moh
Moh

Li
Li

15ｰ

Coal found in Thailand is ranked fromlignite to sub-bituminous|)

Bo
Bo Luang
Luang

17ｰ

|

|

Mae
Mae Chaem
Chaem

21ｰ

VietnamVietnam

Laos
Laos

ChiangChiang Muan
Muan

ChiangChiang Mai
Mai

105ｰ

103ｰ

|

Myanmar
Myanmar

|

19ｰ

101ｰ

99ｰ

|

97ｰ

|

95ｰ
|

21ｰ

11ｰ

Cambodia
CambodiaAndaman Sea
Sea
AndamanPrachub
Prachub Khirikhan
Khirikhan

|

11ｰ

)

Gulf ofof Thailand
Thailand
Gulf

Largest reserve is Mae Moh basin
located in Lampang province

VietnamVietnam|

Surat
Surat Thani
Thani
)

|

)

9ｰ

9ｰ

Si
Thammarat
NakhonNakhonNakhon Si
Si Thammarat
Thammarat

Krabi
Krabi
Kantang
Kantang)

Songkhla
Songkhla|

Active Coal Mine
Suspended Coal Mine

|

7ｰ

)

7ｰ

Lignite produced at Mae Moh basinsof EGAT is used mainly as fuel for
power generation

Yala
Yala
North

95ｰ

|
97ｰ

|
99ｰ

Malaysia
Malaysia
|
101ｰ

0

|
103ｰ

Electricity Generating Authority of Thailand

Source : Department of Mineral Fuel

!

50

100

Kilometers

|
105ｰ

5ｰ
資料367
|

Indonesia
Indonesia|

5ｰ |Department
Department
DepartmentofofofofMineral
MineralMineralMineralResources
Resources
Resources
Resources
Department
Department
DepartmentofofMineralMineralResources
Resources
March
March
March12,12,
12,12,2001
2001
2001
2001
March
March
March
12,
12,
2001
2001

2

Coal Reserves of Thailand

Electricity Generating Authority of Thailand

資料368

3

Lignite Production and Consumption in Thailand, 1996-2008p
Unit : thousand tons
Consumptions
Year

Production

Total

Electricity

TobaccoCuringCementOthers2001

19,617

19,93215,807

34

3,150

941

2002

19,602

19,54015,084

54

3,416

986

2003

18,843

17,964

15,455

25

1,646

838

2004

20,06020,547

16,539

26

2,968

1,014

2005

20,87821,046

16,586

22

3,389

1,049

2006

19,001

20,547

15,825

13

2,204

810

2007

18,23918,121

15,811

10

1,693

607

2008p

18,056

18,66816,295

5

1,743

625

Source : Department of Alternative Energy Development and Efficiency (DEDE) , 2009

Electricity Generating Authority of Thailand

資料369

4

Trends of Coal Demand in Thailand
In 2021: Total Demand = 48 million tons
(Industry: 19.7; Electricity: 28.3)
60,000

Projection
Total

40,00030,000Electricity

20,000Industry

10,000

2020

2017

2014

2011

2008

2005

2002

1999

1996

1992

1989

0
1986

Coal Demand ('000 tons)

50,0002008: Total Demand = 34.8 million tons
(Industry: 13.4; Electricity: 21.4)
Electricity Generating Authority of Thailand

資料370

From Power
Development Plan
2007 Revision 2,
4 Coal-fired
power plant withtotal capacity of
2,800 MW will be
operated each year
from 2016 to
2017.

Year

5

Coal Imported of Thailand, 2000 - 2008
x1,000 tons
18,00016,00014,00012,00010,000
8,000
6,000
4,000
2,000
0
2000

2001

2002

2003

Total

IPP

Electricity Generating Authority of Thailand

2004

SPP

資料371

2005

2006

2007

2008

Industry6

Thailand’s Installed Capacity
Classified by Type of Power Plant

Classified by Producer
IPPs
12,151.59 MW(42.7%)

SPPs
2,072.8 MW(7.3%)

Combine Cycle
16,004 MW(56.2%)
Renewable
234.03 MW(0.8%)

Thermal8,050.4MW(28.3%)

EGAT
13,617.11 MW(47.8%)
Power Purchase from
Neighboring Countries
640 MW(2.2%)

Total Installed Capacity (As of June 2009)
Peak Demand (As of 24 April 2009)

Electricity Generating Authority of Thailand

資料372

Hydro
3,424.18 MW(12%)
Gas Turbine & Diesel
128.9 MW
(0.5%)

Power Purchase from
Neighboring Countries
640 MW(2.2%)
28,481.50
22,595.77

MWMW
7

Thailand’s Generation Mix
Classified by Producer

IPPs
5,907.05 GWh(46.14%)EGAT
5,493.85 GWh(42.91%)

Classified by Fuel Type

SPPs
1,165.5 GWh(9.1%)Natural Gas
9,217.7 GWh(72%)

Power Purchase from
Neighboring Countries
236.85 GWh(1.85%)

Hydro
368.5 GWh
(2.9%)(As of July 2009 = 12,803.25 GWh)

Electricity Generating Authority of Thailand

資料373

Others241.81GWh(1.9%)

Lignite andImported Coal
2,734.5 GWh(21.4%)
Purchases + Diesel
238.8 GWh
(1.9%)

8

Thailand Power Development Plan (PDP 2007 Revision 2)
EGAT Projects
Year

Project Names

Private Companies
IPPs
(MW)

MW

Purchase from Neighboring Countries

SPPs
(MW)

2009

South Bangkok combined cycle power plant #3
Bang Pakong combined cycle power plant #5
RPS

710
710
9

26.5

2010

RPS
North Bangkok combined cycle power plant #1

35
670

90

2011

RPS

38
Total capacity at the end of 2011

IPP_Coal 660

15,073989

2013
Wang Noi Combined Cycle Power Plant #4
Chana Combined Cycle Power Plant #2

800
800

Thermal Power Plant (Coal) #1-2

2x700

Nam Ngum 2

Theun Hinboun – ExpandedMW

Reserve
Margin(%)

920

30,14822.4

30,94223.9

597

32,417

23.4

2,157

32,417220

33,626

19.9

IPP_Gas 1 ,600
IPP_Coal 270

540

36,036

19.9

IPP_Coal 270
IPP_Gas 1 ,600

90

38,544

15.9

2015
2016

Nam Theun 2

15,188

2012

2014

250

Project Names

Total
Capacity(MW)

New IPP

800

Purchase from Neighboring Countries

450

37,81915.7

Purchase from Neighboring Countries

450

39,721

15.7

3,277

39,721

Total capacity at the end of 2016

17,021

19,4242017

Thermal Power Plant (Coal) #3-4
Southern Combined Cycle Power Plant

2x700
800

Purchase from Neighboring Countries

450

41,87715.6

2018South Bangkok combined cycle power plant #4-5
North Bangkok combined cycle power plant #2
Bang Pakong combined cycle power plant #6

2x800
800
800

Purchase from Neighboring Countries

450

44,84616.8

2019

Bang Pakong combined cycle power plant #7
New EGAT Power Plant

800
800

Purchase from Neighboring Countries500

46,757

15.8

2020

Thermal Power Plant (Nuclear) #1
New EGAT Power Plant

1,000
800

New IPP 2x 800

Purchase from Neighboring Countries500

49,12816.8

2021

Thermal Power Plant (Nuclear) #2
Southern Combined Cycle Power Plant

1,000
800

New IPP

Purchase from Neighboring Countries500

52,028

15.8

Total capacity at the end of 2021

26,027

資料374

20,325

5,677

52,028

Total added capacity (2009-2021)

15,772

7,600

1,986

5,037

30,395

Electricity Generating Authority of Thailand

800

9Generation Mix for PDP 2007 Revision2, Thailand(Classified by Fuel Types)

GWh

Nuclear320,000

DeiselRenewable
Power Purchase from Neighboring Countries

280,000

2%

Fuel Oil2%

Imported Coal

240,000

2%

Lignite2%

Natural Gas

200,000

160,0002%
8%

120,000

2%
3%

Hydro

2%
5%
8%

9%

3%
2%
6%
9%

3%
7%
10%

6%
10%
9%

7%

6%
11%

11%

5%

10%

10%

16%

15%

9%
8%

7%
15%

3%

19%

8%

8%

7%

18%

17%
7%

6%

6%

7%

9%

11%

11%

11%

10%

73%

70%

69%

67%

69%

68%

69%

65%

61%

62%

63%

61%

60%

4%

4%

4%

3%

3%

3%

3%

3%

3%

2%

2%

2%

2%

2009

2010

2011

2012

2013

2014

2015

2016

2017

2018

2019

2020

2021

80,00040,0000Electricity Generating Authority of Thailand

資料375

10

Coal Demand for Power Generation in Thailand
Contracted Capacity(MW)

Fuel Requirement(Mton)(4x150)+(6x300)

16.1

Independent Power Producer- BLCP

2x673.25

3.7

Sub total

3,746.5

19.7

Small Power Producer (Firm)- GLOW SPP3
- National Power Supply- TPT Utility

2x90
2x90
10

0.66
0.66
0.26

Subtotal

370

1.58

Grand Total

4,116.5∼21.28New Coal-fired Power Plant
Project

Contracted Capacity(MW)

Fuel Requirement(Mton)

EGAT

4x700

10.2

Independent Power Producer

660+540

3.7

Total

4,000

∼14

Existing Coal-fired Power Plant
EGAT- Mae Moh

(As of December 2008)

Electricity Generating Authority of Thailand

資料376

11

Power generation technology of
EGAT’s new coal-fried power plants
Technology

pulverized coal fired, steam-electric generation with nominal
output of 700 – 1,000 MW

BoilerSupercritical pressure or Ultra-Supercritical pressure

Steam turbine

Tandem compound type

Control equipment
Environmental

NOx :
SOx :
Particulate :FuelImported Coal (bituminous or Sub-bituminous Coal)Electricity Generating Authority of Thailand

Selective Catalytic NOx Removal (SCR)
Seawater Flue Gas Desulphurisation Plant (FGD)
Electrostatic Precipitator (ESP)

資料377

12

EGAT Coal Procurement Strategy• EGAT is procurement the high quality coal from the foreign tothoroughly support power plant life with adequate quantities.
• Contracting mix to take advantage of coal market positions• Investment in overseas coal mines for coal supply security• Quality requirements : Bituminous and Sub bituminous coal
• Competitive delivered cost
• To mitigate the risks:- Diversification of countries- Diversification of coal mines- Diversification of load ports

Electricity Generating Authority of Thailand

資料378

13

DEDE Activities on CCT•Feasibility Study on CCT Application to Industries•Detail Design on CCT•Demonstration of Coal Gasification•Feasibility Study on Coal Water Mixture•Cooperation with Private Sector in CWM Research•Clean Coal Technology Transfer Project (NEDO, CCUJ)
RemarkDEDE : Department of Alternative Energy Development and Efficiency (DEDE)
Electricity Generating Authority of Thailand

資料379

14

Conclusion• Coal will remain one important fuel in Thailand’s fuel mix to enhanceenergy supply security of the economy• Environment impact and social perception on coal will play adramatic role in power projects.
• The application of CCT by both power generation and industrial
operators will reduce pollution emission from coal utilization
CCTs

Supercritical PC
Cogen.

CFBC

Industry

CWM

Electricity Generating Authority of Thailand

資料380

16

BLCP Coal-fired Power Plant

End of presentation
Thank you for your attention

www.egat.co.th

Electricity Generating Authority of Thailand

資料381

17

Emission Standards for New Power Plants

Electricity Generating Authority of Thailand

資料382

18

U.S. Coal Supply & Demand
Cleaner Coal: Moving Towards Zero Emissions
APEC Expert Group on Clean Fossil Energy
October 13, 2009
Inchon, Korea
Dr. William Watson
Office of Coal, Nuclear, Electric & Alternate Fuels
U.S. Energy Information Administration

資料383

Discussion Points• Emphasis on Environmentally-Friendly Coal
– Waxman (California) and Markey (Massachusetts)
CO2 Cap and Trade Bill, H.R. 2454, Title III• Reduction in CO2• Economic Impacts– Coal & Electricity Prices– Coal & Electricity Use– Household Budgets & GDP• Future Prospects for U.S. Coal

資料384

2

Waxman-Markey:- Covers Approx. 84% of U.S. GHG Emissions- 17% Reduction by 2020 and 83% Reduction by 2050, relative
to 2005- Covers Elec. Generators, Liquid Fuel Refiners & Importers,
Manu. Of Fluorinated Gas, Large Industry, and NG Distri.
- 2 billion metric tons of offsets per year
9000
(million metric ton CO2-equivalent)
8000
7000
6000

Cumulative 24.6 BMT
Out of 113 BMT

5000
4000
3000

T o tal E m issio n s
BAU
Co veredE m issio n s BAU
Cap o nE m issio n s

2000
1000

4

資料385

30
20

25
20

20
20

15
20

10
20

20

05

0

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

U.S. Faces a Range of Possible Paths¾ Reference Case – Current Environmental Regulations, Which
Exclude Cap and Trade¾ Basic Case – Cap and Trade Without Major Obstacles¾ Zero Bank Case – Basic Case Plus Low-Cost No-Carbon Alternative
Energy¾ High Offsets Case – Basic Case Plus Immediate Availability ofInternational Offsets (= 1.5 billion metric tons of carbon
dioxide)¾ High Cost Case – Basic Case But No-Carbon Energy is High Cost(+50%)¾ No International Case – Basic Case But Severely Limited International
Offsets¾ No International/Limited Case – Same as No International Case plus
Constraints on Growth of Nuclear, Fossil with CCS, andDedicated Biomass
3

資料386

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

A carbon tax or cap/trade increases coal prices
more than other fossil fuel prices
FuelDel. Price
CO2
Content (2007, allTons Per sectors,
per million
million
Btu)
Btu

Impact of $10 per
ton CO2 value

Impact of $50 per
ton CO2 value$

percent$

percent

Coal

0.094

1.81

0.94

51.9

4.70

260

Oil

0.074

20.31

0.74

3.6

3.70

18.2

Nat.
Gas

0.053

9.01

0.53

5.9

2.65

29.4

* A $25/ton value on CO2 raises gasoline prices by about 23 cents per gallon

5

資料387

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

Sources of Abatement, Basic Case
Offsets Would be Very Important in Early Transition(reduction relative to the ref. case, million metric tons CO2-equivalent)
4000

Offsets, In tern atio n al

3500

Offsets, No n co vered
em issio n s
Offsets,
Bio seq u estratio n
No n -E n erg y-CO2
co vered em issio n s
Carb o n Cap tu re an d
S to rag e
E n erg y-Related CO2

3000
2500
2000
1500
1000
500

20

30

25
20

20
20

15
20

20

10

0
6

資料388

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

t
t/L n a
im l
ite
d

at
rn

In

o
N

te

7

N

o

In

H

L iq u id F u els
Natu ral G as
Co al
Nu clear
Ren ew ab le

io

C
h

ig

ffs

et

os

s

k
O
h

H

ig

ro

B

an

as

B
Ze

en
er
ef
R

ic

45
40
35
30
25
20
15
10
5
0
ce

q u ad rillio n Btu

U.S. Primary Energy Consumption, 2030
Coal Impacted the Most

資料389

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

U.S. Coal Production Alternate Cap/Trade Cases, 1970-2030
In cases with most constraining options, coal production cut by 60% by
2030
Basic

Zero BankHigh Offsets

No International

No Int/Limited

ReferenceHigh Cost

2,000

1,500

(Million short tons)
Reference

1,000

Basic
500

Projections

History
0
1970

1980

1990

2000

2007

2020

2030

8

資料390

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

Western U.S. Coal Production Alternate Cap/Trade Cases, 1970-2030
PRB Coal Production on Path to Minimal Production, Just a Matter ofTime
B a s ic

Ze ro B a n k

Hig h O ffs e ts

No In te rn a tio n a l

No In t/L im ite dRe fe r e n c e

Hig h C o s t

1 ,0 0 0

800

Reference(million short tons)

600

400

Basic

200

Projections

History
0
1970

1980

1990

2000

2007

2020

2030

資料391

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

9

Allowance Prices, Alternate Cap/Trade Cases
200(2007 dollars per metric ton CO2-equivalent)

180
160

Basic
Zero Ban k
Hig h Offsets
Hig h Co st
No In tern atio n al
No In t/L im ited

140
120
100
80
60
40
20

30
20

20

27

24
20

21
20

18
20

15
20

20

12

0
10

資料392

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

Energy-Related CO2 Emissions by Sector, 2030
Electric Power Accounts for Most Emission Reduction
million metric ton CO2

E lectric P o w er
T ran sp o rtatio n
In d u strial
Bu ild in g s

ence
Ze B a
si
r
c
o
H
B
ig
an
h
O
k
f
N
H f seoi
In g h t steCr
N n a os
o
t
t
i
In o
t /L n a
im l
ite
d

R

ef

er

20

07

7000
6000
5000
4000
3000
2000
1000
0

11

資料393

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

Electricity Demand Growth by Case, 2007-2030
2.50%

2.39%

2.00%
1.50%

1.15%
0.72%
0.72%
0.64%

0.90%

1.00%

0.57% 0.56%

0.50%

0.21%

io
N

o

te
In

12

In

rn

at

h

t/L n a l
im
ite
d

t
os
C

et
ig
H
No

H

ig

h

O

ffs

an
B

ro

s

k

ic
as

e

B
Ze

fe

re

nc

07
20
Re

to
00

20

19

90

to

20

00

0.00%

資料394

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

Coal Costs to Electricity Producers, 2030
(2007 dollars per million Btu)

$20
$18
$16
$14
$12
$10
$8
$6
$4
$2
$0

17.83
10.04
6.83

6.13
3.85

3.97

2.04 1.69 1.87 1.86 1.81 1.45 1.54
t
ic
e
k
s
s
s
c
d
t
n
al
a
o
n
e
e
a
t
n
B
C
i
B
fs
re
o
f
i
h
e
m
t
o
i
f
O
r
g
a
L
i
e
e
/
n
h
R
H
Z
g
nt
er
i
I
t
H
o
In
N
No
Co al Allo w an ce Co st

13

資料395

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

Electricity Sector CO2 Emissions by Case
Currently, 92% of Coal Used in Electric Sector
WM Allowance Price Has Greatest Impact on Coal Prices
3000(million metric tons)

2500

Referen ce
Basic
Zero Ban k
Hig h Offsets
Hig h Co st
No In tern atio n al
No In t / L im ited

2000
1500
1000
500

30
20

20

25

20
20

15
20

10

14

20

20

05

0

資料396

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

Electricity Prices by Case(2007 cents per kilowatt-hour)
2018

Referen ce
Basic
Zero Ban k
Hig h Offsets
Hig h Co st
No In tern atio n al
No In t / L im ited

16
14
12
10
8
6
4
2

30
20

25
20

20
20

15
20

10
20

20

05

0
15

資料397

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

Average Change in Household Energy Expenditures, 2030
(2007 dollars)$2,000

An n . In cre. Cap ital E xp en d .
L ig h t Du ty V eh icle E xp en d itu res$1,500

Ho m e E n erg y E xp en d itu res$1,000
$500
$0
B

i
as

c
Ze

ro

B

k
n
a
Hi

gh

O

ffs

s
et
Hi

gh

C

No

t
s
o
In

資料398

t

n
r
e

io
t
a

l
a
n

No

I

/
t
n

m
Li

ite

d
16

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

Fuel and Power Wholesale Prices(Percent Change Compared to Reference Case)
100%
90%
80%

Basic
Zero Ban k
Hig h Offset
Hig h Co st
No In tern atio n al
No In t/L im ited

70%
60%
50%
40%
30%
20%
10%

30
20

20

27

24
20

21
20

18
20

15
20

20

12

0%
17

資料399

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

Consumer Energy Prices(Percent Change Compared to Reference Case)
100%
90%
80%

Basic
Zero Ban k
Hig h Offset
Hig h Co st
No In tern atio n al
No In t/L im ited

70%
60%
50%
40%
30%
20%
10%

30
20

20

27

24
20

21
20

18
20

15
20

20

12

0%
18

資料400

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

Real GDP
(Percent Change Compared to Reference Case)
0 .5 %

.

.

.

.

.

.

.

0 .0 %Basic
Zero Ban k
Hig h Offset
Hig h Co st
No In tern atio n al
No In t/L im ited

-0 .5 %
-1 .0 %
-1 .5 %
-2 .0 %

19

-2 .5 %

資料401

Source: Energy Market and Economic Impacts of H.R. 2454, the American Clean Energy and Security Act (August 2009).

Summing Up• U.S. Coal Prospects: Technology development andoffsets are the key drivers of impacts from GHG
reduction– Technology breakthroughs needed to keep costs of CO2
reduction at moderate levels– Policies to increase accessibility to offsets can spread outtransition costs– Disproportionate impact on coal: coal use falls, some paths
less drastic than others; no question of fall, only how
quickly• Macroeconomic Impacts– Household expenditure on energy could be significantly
higher with cap and trade– GDP growth could be significantly dampened for several
decades under cap and trade

資料402

20

OUTLOOK OF COAL DEMAND / SUPPLY &POLICY IN MALAYSIA

Suruhanjaya Tenaga(Energy Commission)
Malaysia

資料403

Coal Utilisation Framework

資料404

Acts and Policies• Petroleum Development
Act 1974• National Petroleum Policy
1975• Environment Act 1974

• National Energy Policy 1979

• Electricity Supply Act 1990

• National Depletion Policy 1980

• Gas Supply Act 1993

• Four Fuel Policy 1981

• Energy Commission Act
2001• Five Fuel Policy 2001

12 October 2009• National Policy on
Environment 2002

APEC EGCFE
Incheon 2009
資料405

Malaysia Air Quality Guidelines

12 October 2009

APEC EGCFE
Incheon 2009
資料406

Source: Department of Environment, Malaysia

Coal Supply Committee

Established in 2003;

Energy Commission as the secretariat for the Committee;

To monitor the use and supply of coal for electricity
generation;

Provides regular feedback to the Government;Comprises of representatives from Government andindustry players;The Committee meets regularly to discuss issues related tocoal.
12 October 2009

APEC EGCFE
Incheon 2009
資料407

Supply / Demand Situation

資料408

Installed Capacity (2009)

Total: 24,608 MW

12 October 2009

APEC EGCFE
Incheon 2009
資料409

Generation Mix

Total: 113,823 GWh

12 October 2009

APEC EGCFE
Incheon 2009
資料410

Coal Supply By Country in 2009

South Africa, 5%Australia, 11%Indonesia, 84%
Source: TNBF

12 October 2009

APEC EGCFE
Incheon 2009
資料411

Power Generation Coal Demand for Peninsular
Malaysia (up to 2010)
Plant

Max. Annual
Capacity Commissioning
Consumption
(MW)
Year
(Mtpa)TNB Kapar Ph. 2

600

1988

1.50

TNB Kapar Ph. 3

1000

2001

2.50

TNB Janamanjung

2100

2002/03

6.00

Tg. Bin - IPP

2100

2006/07

5.50

Jimah - IPP

1400

2009

3.50

Total

7200

19.00
Source: TNBF

12 October 2009

APEC EGCFE
Incheon 2009
資料412

Power Generation Coal Demand for East Malaysia

Plant

AnnualCapacity Commissioning
Consumption
(MW)
Year
(Mtpa)

Sejingkat Ph.1

100

1998

0.50

Sejingkat Ph.2

110

2000

0.50

160

TBD

0.50

160

TBD

0.50

Lahad Datu
Ph.1
Lahad Datu
Ph.2

Total

530

2.00
Source: TNBF

12 October 2009

APEC EGCFE
Incheon 2009
資料413

Coal-fired Power Stations in Malaysia

Manjung
2,100 MW6.0 mtpa
Kapar
1,600 MW4.0 mtpa
Jimah
1,400 MW
3.5 mtpa

12 October 2009

Tg. BinSejingkat

Mukah

Lahad Datu

2,100 MW210 MW

270 MW

320 MW

5.5 mtpa

0.5 mtpa

0.5 mtpa

1.0 mtpa

APEC EGCFE
Incheon 2009
資料414

Outlook of Coal Consumption for Peninsular Power
Sector(Million Tonne - Mt)
20
18
16
14
12

Jimah

Mt 10

Tg Bin8

Kapar

Manjung

6
4
2
0
2002

2003

2004

2005

2006

2007

2008

2009

2010

Year

12 October 2009

APEC EGCFE
Incheon 2009
資料415

Source: TNBFCoal Consumption by Sectors

12 October 2009

APEC EGCFE
Incheon 2009
資料416

Source: National Energy BalanceFuel Mix Trend in Power Generation

12 October 2009

APEC EGCFE
Incheon 2009
資料417

•

Oil & Distillate also includes otherfuels(ex. biomass, MSW etc).

•

2008-2013- EC’s forecast.

Factors Influencing Supply / Demand
The Challenge of Coal
Demand from Buyers

Supply Challenges

Logistics Glitches

Weather and Force
Majeure12 October 2009

 Increasing coal imports from China, India
 High demand growth in China, India, Indonesia and other developing
nationsPort problems and congestion
Labour unrest
Derailments
Port allocation cut








Rising oil prices used for coal production
Shortage of mining equipments
Shortage of manpower
Higher stripping ratio
Lowering of coal quality
Government intervention on price and supply

 Unpredictable rainy season resulting in mine flooding
 Storm causing vessels unable to berth
APEC EGCFE
Incheon 2009
資料418

Factors Influencing Coal Utilisation in Malaysia
Natural Gas

Coal






Uncertainty in production due to age of existing fields
Increase of production costs due to deepwater exploration
Transfer of costs to consumers
Impact from fuel diversification policy & government price subsidy






High reliance towards imported coal
Domestic production still lagging behind
Quality to match plants’ requirements
Technology to protect environment

Hydroelectric Transfer of power to load centres
 Capital intensive
 More stringent impact analysis required due to environmental concern

Oil / Distillate

 Back‐up fuel for large gas units Rural / off‐grid electrification

Renewable Energy
12 October 2009

 High potential
 Capital intensive
APEC EGCFE
Incheon 2009
資料419

Promotion of Clean Coal
Technology Awareness

資料420

Proposed Key Initiatives•Promoting “Clean Coal Technology” utilisation awarenessamong Malaysian public via universities. MARA University ofTechnology has been identified to be briefed on “Clean Coal
Technology” in July 2009

•Malaysia’s Initiative for a Cleaner Environment through“Clean Coal Technology” implemented by Manjung Power
Station

資料421

Manjung Power Station•Plant type:

Pulverized Coal Firing•Net Capacity:

2100 MW (nominal)•Plant Configuration:

3 x 700 MW•Plant site:

Man‐made reclaimed island

資料422

N

Manjung Power Station’s Location

Segari PowerPlant

PANGKORISLAND

Manjung
District

35 km

SITIAWAN

LUMUT

Project Site
Manjung Power
plant
資料423

Clean Coal Combustion Technologies•Pulverized Fuel Firing (PFF)•Flue Gas Desulphurization (FGD)•Electrostatic Precipitator (ESP)•Low sulphur & low ash sub‐bituminous grade coal
•Low NOx burners•Provision of high chimney (200m) for exhaust gas
資料424

Emission Standards (mg/Nm3)
DOE

World Bank

Manjung(local council)

Particulate

400

50

50

Sulfur Oxide

3500

750

750

Nitrogen
Oxide

1700

650

650

Cooling Water Temperature Rise: 8 deg C
資料425

Mount Kinabalu – View from the Top

THANK YOU&TERIMA KASIH
Ahmad Johari Jaffar
Energy Commission, Malaysia
for
APEC EGCFE Incheon 200912 October 2009

APEC EGCFE
Incheon 2009
資料426

12‐14 October 2009

(7)セッション 4

資料427

Coal in Canada
Kevin Stone

2009 APEC Clean Fossil Energy Technical and Policy Seminar
Incheon, South Korea, October 13, 2009
資料428

Canada’s Natural Resources – Now and for the FutureOutlines Canada’s coal sector profile The role of coal in Canada Coal reserves and resources in Canada Canadian coal consumption, production, and exports
 Canadian coal demand and supply forecast
 Government policy
 Summary

資料429

Canada’s Natural Resources – Now and for the FutureCoal Sector Profile A mid-sized coal producing sector: annual production
capacity over 70 Mt (40% coking and 60% thermal)
 24 producing coal mines - 22 open-pit and 2 undergroundmines (22 in operation and 2 idled at the end of 2008)
 A work force in excess of 5,000
 21 coal-fired power generation plants accounting for 90%
of Canada’s coal consumption
 The sector is serviced by coal-transporting railways, ports,
equipment suppliers, exploration and engineering firms
 The Coal Association of Canada is an industry association

資料430

Canada’s Natural Resources – Now and for the Future

Mines (24), Ports and Railroads

資料431

Canada’s Natural Resources – Now and for the Future

Role of Coal in Canada Accounts for 10.2% of Canada’s primary energy supply Oil 35.3%; Gas 29.5%; Hydro 11.3%; Nuclear 9.5%; Renew 4.7%

 Coal-fired generation supplies 15.3% of Canada’s electricity
demand and uses 90% of Canada’s coal consumption. Coal isalso used in iron and steel, and cement manufacturing.
 Domestic production supplies 2/3 of Canada’s 60 Mt coalconsumption and 1/3 is supplied by imports.
 Canada produced 68 Mt of coal in 2008, valued at $4.3 billion.
 Canada exports over 40% of its coal output, and exported 32.4
Mt in 2008, mainly coking coal (26.5 Mt, valued at C$5.6 billion).
 Coal is the no. 1 commodity carried by rails (34 Mt in 2008) andhandled by ports (53Mt in 2008).
資料432

Canada’s Natural Resources – Now and for the Future

Canadian Electricity Generation
Canada, Electricity Generation by Sources, 2007

Gas
8.5%

Oil
1.6%

Wood
0.3%

Others0.6%

Nuclear
14.3%

Hydro
59.0%

Coal
15.3%
Wind & Tide
0.5%

In 2007, 53.1 Mt of coal was consumed for electricity generation
Source: Statistics Canada, NRCan
資料433

Canada’s Natural Resources – Now and for the FutureCoal Deposits in Canada

資料434

Canada’s Natural Resources – Now and for the Future

Reserves and Resources (2005)
 Proven amount in place, 8.7 billion tonnes
 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
Source: World Energy Council, Survey of Energy Resources
資料435

Canada’s Natural Resources – Now and for the Future

Canadian Coal Consumption
Canadian Coal Consumption
70

million tonnes

60

63
57

59

62

59

62

62

59

60

58

61

50
40
30
20
10

Annual Coal Consumption

20
07

20
06

20
05

20
04

20
03

20
02

20
01

20
00

19
99

19
98

19
97

0

Used for Coal-Fired Electricity Generation

Source: Statistics Canada, NRCan
資料436

Canada’s Natural Resources – Now and for the FutureCoal Consumption
 Coal is primarily consumed for electricity generation.
 Canada consumed 60 million tonnes of coal in 2007.
 The 21 coal-fired generation plants consumed 53 million
tonnes to produce electricity.
 A small portion is used in iron and steel-making, cement,
and other industries. In 2007, Canada’s steel industry used
about 4 million tonnes. Cement and other Industries usedclose to 3 million tonnes.
 Availability and low cost makes coal the choice of fuel forelectricity production in some provinces such as Alberta
and Saskatchewan.

資料437

Canada’s Natural Resources – Now and for the Future

Canadian Coal Production
Canadian Coal Production
80
70

m illio n to n n es

60

Coking Coal

50
40
30

Thermal Coal

20
10

Source: Statistics Canada, NRCan
資料438

Canada’s Natural Resources – Now and for the Future

08
20

07
20

06
20

05
20

04
20

03
20

02
20

01
20

00
20

99
19

98
19

19

97

0

Coal Production
 Canada is a mid-sized coal producer, ranking 14th among
global coal-producing countries (2008).
 Canada’s coal production has remained relatively steadyover the past decade.
 In 2008, Canada produced 68 million tonnes of coalvalued at C$4.3 billion.
 Close to 60% of the coal production was thermal coal andmore than 40% was metallurgical (coking) coal.
 Thermal coal production is mainly for domestic
consumption.
 Coking coal, almost all of the output, is for exports.
資料439

Canada’s Natural Resources – Now and for the Future

Canadian Coal Trade
Canadian Coal Trade40
35

m illio n to n n es

30
25
20
15
10
5

資料440

Canada’s Natural Resources – Now and for the Future

08
20

06

05

07
20

Imports

20

Exports

20

04
20

03

02
20

00

01
20

20

Source: Statistics Canada, NRCan

20

99
19

98
19

19

97

0

Coal Trade Canada exports its entire coking coal output and is one of theworld’s leading seaborne coking coal suppliers.
 In 2008, Canada exported 32.4 million tonnes of coal, of which
coking coal totaled 26.5 million tonnes valued at $5.6 billion.
 Canada exports coal to more than 50 countries. Asia was
Canada’s largest coal trading partner, accounting for 63% of
Canada’s total exports in 2008; Europe and the Middle East was
the second, accounting for 22%; and the remainder was toAmericas, accounting for 15%.
 Canada imports coal into central and eastern Canada due to its
geographic proximity to the U.S. east and central coal-producing
regions. About 80% of coal imports go to Ontario and is mostly
used for coal-fired generation.
 Canada imported 20.6 million tonnes of coal in 2008.
資料441

Canada’s Natural Resources – Now and for the FutureCoking and Thermal Coal Exports
Canadian Coking and Thermal Coal Exports
40
35

million tonnes

30
25
20
15
10
5

6

7

8

20
0

20
0

3
20
0

20
0

2
20
0

Canada’s Natural Resources – Now and for the Future

5

1
20
0

資料442

20
0

0
20
0

Coking Coal

4

9
19
9

Source: Statistics Canada, NRCan

20
0

8
19
9

0

Thermal Coal

Canadian Export Destinations
Canadian Coal Export Destinations

Percentage

100
90
80
70

82
75
65

60
50
40
30
20
10
0

55

52
31

28

26

21
10 8

1990
Source: Statistics Canada, NRCan

14
10

1995

17

17

2005

2006

14

2000
Asia

Europe
資料443

Canada’s Natural Resources – Now and for the Future

63

60

Americas

22
14

16

2007

2008

Recent Coal Developments
 Six new coal mines have come on stream since August 2004
 Willow Creek (2 Mt, PCI – currently idled) - WCC
 Grande Cache (2 Mt, coking) - GCC
 Cheviot (2.8 Mt, coking) - Teck
 Brule (1.6 Mt PCI) - WCC
 Wolverine (2.8 Mt coking) - WCC
 Trend (2 Mt coking) - PRC
 Two projects were approved Herman Mine Project (1 Mt PCI coal) by WCC, possible start-up of
production in 2011
 Donkin Coal Mine Project (3.7-5.2 Mt/y, thermal) by Donkin, initial
production could start in 2010 on a smaller scale (0.5 Mt/y) and fullproduction could begin in 2012

資料444

Canada’s Natural Resources – Now and for the Future

Recent Coal Developments (cont’d) Six coal projects are currently going through regulatory
approval process Fortune Minerals – Mount Klappan (1.5 Mt, anthracite)
 Hillsborough – Horizon (1.6 Mt, coking) Cline Mining – Lodgepole (2 Mt, coking) Hillsborough – Wapiti (800,000 t, thermal) Dehua - Gething (2 Mt, coking) PRC – Roman (2 Mt, coking) If approved, the projects would add a total of 9.9 Mt to the
Canadian supply from 2012.
 Canadian production would reach 80 Mt by 2015.
 Majority of the increased coal output is for exports.
資料445

Canada’s Natural Resources – Now and for the Future

Canadian Supply Forecast
Canadian Coal Supply Forecast
90
80

million tonnes

70
Coking Coal

60
50
40
30

Thermal Coal

20
10
0
2010

2011

2012

2013
資料446

Canada’s Natural Resources – Now and for the Future

2014

2015

Canadian Export Forecast
Canadian Export Forecast
60

m illion ton n es

50
40
30

6

11

11

7

8

39

39

39

39

2012

2013

2014

2015

6

20

31

31

2010

2011

10
0

Coking Coal
資料447

Canada’s Natural Resources – Now and for the Future

Thermal Coal

Canadian Demand Forecast
Canadian Coal Demand Forecast
60

60

60

59
56

55

55
47

47

40
30
20
10

Annual Coal Consumption

Used for Coal-Fired Electricity Generation
資料448

Canada’s Natural Resources – Now and for the Future

20
15

20
14

20
13

20
12

20
11

20
10

20
09

0
20
08

million tonnes

50

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, labour, health (shared),safety, environmental protection (shared), reclamation, royalty regime

Federal responsibilities
 International affairs, trade, investment, fiscal and monetary policy,
science and technology, health (shared), environmental protection(shared), and Aboriginal affairs

資料449

Canada’s Natural Resources – Now and for the FutureGovernment Policies
Canada’s Minerals and Metals Policy promotes partnerships for sustainable mining
 affirms provincial jurisdiction over mining
 delineates role in minerals and metals tied to federal
responsibilities
 commits to pursue partnerships with stakeholders toaddress issues within its jurisdiction (environment, scienceand international trade)

Canada’s Environmental Policy
 ensures protection of the environment in coal mining
operations
資料450

Canada’s Natural Resources – Now and for the Future

Minerals and Metals Policy Implements a sustainable development approach Principles of SD-based decision-making

 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, science-based
management of substance Promotes Aboriginal involvement in mining activities
 Science and technology: progress through innovation
 Promoting partnerships on S&T

 Provides leadership in the implementation of SD Promoting free trade, cooperation and sound management
資料451

Canada’s Natural Resources – Now and for the Future

Environmental Policies
Canadian Environmental Production Act and Canadian
Environmental Assessment Act, and provincial laws, ensure
protection of the environment in mining operations and newmine projects
 Producers must comply with laws and regulations
 Proponents for new mines must conduct environmental
impact assessment
 reviewed and approved by provincial and federal agencies

 Operations must minimize negative environmental
effects
 Producers must reclaim and rehabilitate the mine site certification by provincial authority
資料452

Canada’s Natural Resources – Now and for the FutureSustainable Mining Practices
 Canada’s coal producers ensure that mining activities,
such as the removal of vegetation, relocation of
overburden, construction of roads, storage of waste rocks,
reclamation of previous mined areas, and mining
operations, are done in a way that manages the negative
effect on the environment.
 Canada’s coal sector has been recognized for its progresson sustainable mining practices.
 Multiple awards on mine reclamation and rehabilitation
have been given to several coal mines across Canada.

資料453

Canada’s Natural Resources – Now and for the FutureSummary Coal is an abundant and widely distributed resource inCanada. Coal is affordable and readily available. The
current proved coal reserves could support 100 years of
production.
 With sustainable mining practices and clean coal technology
development and deployment, coal will continue to play animportant role in Canada’s energy supply.
 Coal will have the highest annual growth rate among fossil
fuels to 2030. 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.
 Canada has a mature coal industry with an experienced
work force.
資料454

Canada’s Natural Resources – Now and for the Future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455

Canada’s Natural Resources – Now and for the Future

Annex 1.

Coal Mine Details

資料456

Canada’s Natural Resources – Now and for the Future

Annex 2.

Coal-Fired Generation Plants

資料457

Canada’s Natural Resources – Now and for the Future

Annex 3.

Railways and Coal Terminals

 Canadian Pacific Railways
 Canadian National Railways






Westshore Terminals, Vancouver, BC
Neptune Terminals, Vancouver, BC
Ridley Terminals, Prince Rupert, BC
Thunder Bay Terminals, Thunder Bay, ON
International Peer, Sydney, NS

資料458

Canada’s Natural Resources – Now and for the FutureAbbreviations
AB – Alberta
BC – British Columbia
SK – Saskatchewan
MB - Manitoba
NB – New Brunswick
NS – Nova Scotia
ON - Ontario

資料459

Canada’s Natural Resources – Now and for the FutureAbbreviations
Teck - Teck Resources Limited
Teck Coal – Teck Coal Limited (a Business Unit of Teck Resource Limited)
WCC - Western Canadian Coal Corporation
PRC – Price River Coal Inc. (A limited partnership among Anglo Coal Canada
Inc., Northern Energy and Mining Inc., and Hillsborough Resources Limited)
GCC - Grande Cache Coal Corporation
Sherritt - Sherritt International Corporation
OTPP – Ontario Teachers’ Pension Plan
Hillsborough - Hillsborough Resources Limited
TransAlta - TransAlta Corporation
Pioneer - Pioneer Coal Limited
EPCOR – EPCOR Utilities Inc.
Fortune Minerals – Fortune Minerals Limited
Cline Mining - Cline Mining Corporation
Donkin - Donkin Joint Venture (A partnership between Xstrata Coal Donkin
Limited and Erdene Gold Inc.)
Dehua - Canadian Dehua International Mines Group Inc.
資料460

Canada’s Natural Resources – Now and for the FutureAustralia – Coal Demand/Supply Outlook
Department of Resources, Energy and Tourism
Presentation by:John KarasManager, Low Emissions Coal PolicyJohn.Karas@ret.gov.au

資料461

1. Australian Coal Industry Locations

資料462

2. Global Financial Crisis and Coal Trade••••

The coal roller coaster ride over the last year
Coal prices peak in 2008
Sharp demand and price declines in 2009
Impact on metallurgical markets softened by
China increasing reliance on imports• Recent signs of recovery – thermal spot prices up
10%• Australian response – reduce costs, cut back onless profitable operations, equity v loan funding.

資料463

3. Key Statistics for Black Coal
07/08

08/09

09/10

Australian Production (Mt)
Australian Export Volume (Mt)of which Thermal (Mt)
Metallurgical (Mt)
Australian Export Value ($A Billion)

327
252
115
137
32.4

328
262
136
125
54.6

347
270
140
130
29.4

World metallurgical coal trade (Mt)
World thermal coal trade (Mt)

2008
235
704

2009
207
690

2010
213
730

ABARE Estimates and Forecasts

資料464

4. Metallurgical coal import growth(forecast annual average growth 2009-2014)2008 Imports
(Mt)

54

7

6

24

資料465

25

52

12

233

5. Metallurgical coal export growth(forecast annual average growth 2009-2014)2008 Exports
(Mt)

135

29

34
資料466

20

233

6. Australian Exports of Metallurgical Coal
180
150

36
volume

value

30

120

24

90

18

60

12

30

6

Mt

2009-10A$b

1994-95

1997-98

2000-01

2003-04
資料467

2006-072009-10

7. Thermal coal import growth(forecast annual average growth 2009-2014)
15

10

5

-5
2008
Imports (Mt)

Japan

Taiwan

Korea

135

62

73.5

India

EU27

China

World

34

193.9

34

832.4

資料468

8. Thermal coal export growth(forecast annual average growth 2009-2014)2008 Exports
126
(Mt)

42

198

66
資料469

68

33

80

719

9. Australian Exports of Thermal Coal
160

20
volume

value

16

120

12
80
8
40

4
2009-10A$b

Mt

1991-92 1994-95 1997-98 2000-01 2003-04 2006-07 2009-10
資料470

10. Port Infrastructure Expansion Plans
Port

Capacity as at 31 Dec
2008(Mtpa)

PlannedCapacity by 2014
(Mtpa)New South WalesPort Waratah Coal Services
Newcastle Coal Infrastructure GroupPort Kembla

102
18

113
30
18

Queensland
Abbot Point
Brisbane
Dalrymple Bay
Hay Point
Gladstone
Wiggins Island

21
5
68
44
75
-

50
8
85
44
75
25

Total

333

448

資料471

11. East Coast Coal Rail Systems

資料472

12. Conclusions on Coal Supply••••

Australia – an efficient supplier of coal.
The Global Financial Crisis – reduce production, cut
cost.
Infrastructure continues to expand.
Continued collaboration with Japan and othercountries..

資料473

Thank you

資料474

Mr. Redentor T. Morelos
Senior Science Research Specialist
Officer-In-Charge, Commercial Development Section
Geothermal and Coal Resources Development Division
Department of Energy, Philippines•••

He is presently supervising the monitoring of operations of various coal contractors andpermittees to ensure that these are in accordance with mine safety standards and approved
work programs. He supervises the technical evaluation of work programs of coal contractors
and permittees. He supervises the research works at different coal producers and end-users
to gather relevant data on coal information and related technologies. He assists informulating proposed policies related to coal exploration, development, production andutilization.
He attended different local and foreign trainings, i.e., Ventsim Mine Ventilation Software
Training in Australia in January 2009; Coal Bed Methane Technology Training/Workshop in
Colorado, USA in July 2008; Training on Technology Transfer on Clean Coal Technology inJapan in November – December 2003; and Coal Mining and Preparation Training in Japan in
May – July 1995.
He is a licensed Mining Engineer and graduated with a degree of Bachelor of Science in
Mining Engineering at the Mapua Institute of Technology, Manila. He completed academic
units for Engineering Graduate Program at the University of the Philippines, Quezon City.

資料475

COAL SUPPLY and DEMAND OUTLOOK
in thePHILIPPINESby:Mr. REDENTOR T. MORELOS

ENERGY RESOURCE DEVELOPMENT BUREAU
DEPARTMENT OF ENERGY, PHILIPPINES
2009 APEC Clean Fossil Energy Technical and Policy Seminar
Incheon, Korea 12-14 October 2009
資料476

OUTLINE
A. SUPPLY
Coal Resources
Coal Production
Coal Importation
B. DEMAND
Coal Consumption
Power & Energy Mix
Coal-Fired Power Plant Projects
C. Coal Supply & Demand Forecast
D. Challenges & Action Plan
資料477

COAL RESOURCES

資料478

Summary of Regional Coal Reserves (MT)(As of December 31, 2007)
Resource
Potential

Positive
Reserves

Probable
Reserves

In-situReserves

Mineable
Reserves

Cagayan Valley
Cebu

336,000,000

80,104,730

3,695,000

82,568,063

70,182,854

CentralNorthern
Southern

40,000,000
75,000,000
50,000,000
100,000,000
2,500,000
100,000,000
4,500,000
17,000,000
2,000,000
27,000,000
550,000,000
209,000,000
45,000,000
50,000,000
108,000,000
120,000,000
230,400,000
300,300,000

3,354,005
2,229,719
1,282,359
208,000
74,994
1,310,641
1,204,952
5,077,416
93,0007,474,890
120,882,151
29,287,663
34,139,539

4,763,160
655,727
1,870,206

1,667,725
43,820,358
60,978,034
5,984,679

6,529,495
2,666,870
2,529,163
208,000
74,994
1,442,641
2,013,877
6,147,200
93,0008,586,707
150,095,723
69,939,686
38,129,325

3,917,697
1,600,122
1,517,498
124,800
44,996
865,585
1,208,326
3,688,320
55,8007,278,807
127,581,365
47,792,987
22,877,595

23,590,423

66,123,516

67,672,767

40,603,660

2,366,700,000

310,314,532

192,574,467

438,697,511

329,340,412

Davao
MasbateMindoroNegrosPolillo, Batan & Catanduanes
QuezonSamar
Semirara
Surigao
Zamboanga
BukidnonMaguindanao
Sarangani
South Cotabato
Sultan Kudarat
Total

198,000
1,213,387
1,604,675

資料479

Source: DOE

資料480Characteristics of Philippine Coal
Soft to dense (a function of depth)¾ Mostly formed during the Miocene age(23 - 25 million years ago)
¾ Occur in moderately to highly disturbed areas¾ Tapers & pinches-out¾ Developed in lagoonal to shallow marine
environments¾ Lignite to Bituminous type
¾ Heating value from 4,600 – 12,000 BTU/ lb(2,555 – 6,666 kcal/kg)¾ Mostly sub-bituminous type
¾

資料481

COAL PRODUCTION

資料482

Presidential Decree (PD) No. 927
PD 972 (known as the “Coal Development act of 1976”,
amended by PD 1174) governs the coal operations in thePhilippines¾ It promotes the accelerated exploration, development,
production and utilization of coal.
¾ It introduced the coal operating contract system andestablished the appropriate guidelines for coal operations.
¾ The government retains the ownership of Philippine coalresource while the operator, as authorized by thegovernment through the contract system, is assigned theright to explore, develop, produce and market the coalbased on some pre-agreed conditions for a specific periodof time.
¾

資料483

Open Pit Mining of Semirara Mining Corp. in Antique(3.5 million MT annually)

資料484

An excavator is extracting and loading coal into
dump trucks at Semirara open pit

資料485

Underground Mining of IRDC in Albay(Longwall; Room and Pillar Methods)¾

A concreted portal of an inclined shaft¾(with 2-meter height and 3-meter floor)
資料486

The Long
Wall Mining¾ Involves the use of pneumatic picks to cut and remove the coal at the face
¾ The length of working face can vary from 50-100 meters¾ Hydraulic props and sliding bars temporarily support the roof
¾ The roof over the area behind the face is allowed to collapse¾ Over 75% of the coal seam can be extracted using this method
資料487

Coal Washing Plant of MG Mining & Energy Corp. in Surigao del Sur(60 TPH feed capacity and separates coal from waste using cyclones by centrifugal force)

資料488

Total COC = 46
Mindanao = 18
Visayas = 14
Luzon
= 14
As of Aug. 2009
資料489

2008 COAL PRODUCTION

Area

Production
(MT)
(%)

Coal Operator

3,471,596

87.30

Semirara Mining Corporation

24,53315,092
7,322
5,870
297

0.61
0.40
0.20
0.15
0.07

Rock Energy
SamajuLima
Ibalong
Small-Scale Coal Mining

14,353
1,097
15,22532,941

0.36
0.03
0.30
0.61

AdlaonSKI
Ibalong
Small-Scale Coal Mining

Surigao del Sur

238,385

6.00

MG Mining

Zamboanga Sibugay

60,8943,770
52,862

1.53
0.10
1.33

PNOC-EC
Filsystems
Small-Scale Coal Mining

Negros

1,259
31,0850.03
0.80

Calatrava
Small-Scale Coal Mining

Total

3,976,581

Semirara Island, Antique
Batan Island, Albay

Cebu

資料490

1998 – 2008 Historical Coal Production(in Million MT)
4.5

YEAR

PRODUCTION

1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008

1.157
1.177
1.353
1.230
1.665
2.030
2.726
3.163
2.588
3.737
3.977

4
3.5
3
2.5
2
1.5
1
0.5
0
1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008
Production

Source: DOE

資料491

COAL IMPORTATION

資料492

2008 COAL IMPORTATION by SOURCES(in MT)
COUNTRYTONNAGE%¾ INDONESIA

7,348,140

80¾ CHINA

1,111,120

12¾ VIETNAM

357,881

3.8¾ AUSTRALIA

331,808

3.6

RUSSIA

60,0000.6

TOTAL

9,208,949
資料493

1998 – 2008 Historical Coal Importation(in Million MT)
YEAR

IMPORTATION

1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008

4.282
4.858
6.814
7.601
6.417
7.035
7.510
6.656
7.344
7.729
9.209

9
8
7
6
5
4
3
2
1
0
1998

1999

2000

2001

2002

2003 2004
Importation

資料494

2005

2006

2007

2008

COAL CONSUMPTION

資料495

2008 COAL CONSUMPTION by SECTOR(in MMMT)TONNAGE%¾ POWER GENERATION

8.769

71.7

¾ CEMENT

3.063

25.0

¾ INDUSTRIAL PROCESSES

0.403

3.3

TOTAL

12.235
資料496

1998 – 2008 Historical Coal Consumption(in Million MT)
12

YEAR

CONSUMPTION

1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008

5.624
6.416
8.749
8.184
8.431
8.513
9.667
10.03610.062
10.21512.235

10

8

6

4

2

0
1998 1999 2000

2001 2002 2003 2004 2005 2006
Consumption

資料497

2007 2008

1998 – 2008 Historical Coal Production,
Consumption and Importation(in Million MT)
12

YEAR

PRODUCTION

IMPORTATIONCONSUMPTION

1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008

1.157
1.177
1.353
1.230
1.665
2.030
2.726
3.163
2.588
3.737
3.977

4.282
4.858
6.814
7.601
6.417
7.035
7.510
6.656
7.344
7.729
9.209

5.624
6.416
8.749
8.184
8.431
8.513
9.667
10.03610.062
10.21512.235

10

8

6

4

2

0
1998 1999 2000

2001 2002 2003 2004 2005 2006

Production
資料498

Consumption

2007 2008

Importation

Steag Power Plant
2 X 105 MW

資料499

資料500Clean Coal Technologies (CCT)¾Technologies that upgrade the quality of coalproduced by mining, i.e., coalpreparation/washing, sorting and blending
methods¾

Technologies that reduce gas emissions andsuspended particulates in coal combustion, i.e.,
FGD, EP, CFB, etc.

資料501

Coal Preparation
Sorting and Blending¾ The various size fractions are screened anddewatered, then recombined before going
through final sampling and quality control¾ High-quality supplies can be carefully mixed
with lower-quality coals to produce anaverage blend suited to the power plant /cement plant needs

資料502

QUEZON POWER PLANT equipped with Flue Gas Desulphurizer(FGD) and Electrostatic Precipitator (EP)

FGD

EP

資料503

POWER and ENERGY MIX

資料504

POWER MIX

2007

2006

Natural Gas
32%

Natural Gas
29%
Coal
28%

Coal
27%

Hydro
18%

GEOTHERMAL
17%

GEOTHERMAL
18%

Hydro
14%

Oil-based8%

Oil-based
9%2008
Natural Gas
32%
Hydro
16%

Oil-Based
8%

Source: DOE

Coal
26%

資料505

Geothermal
18%

2008 ENERGY MIX

資料506

Source: DOE

COAL-FIRED POWER PLANT
PROJECTS

資料507

COMMITTED and INDICATIVE COAL-FIRED POWER PLANT PROJECTS
Project

Capacity

Proponent

LUZON AREA:(1) CFB Power Plant

50 MW

Asia Pacific EnergyCorp.

(2) 2 x 300 MW Power Plant

600 MW(3) 2 x 150 MW Power Plant

LocationTargetCompletion

StatusPampanga

2010

Indicative

GN Power

Bataan2012

Indicative

300 MW

Redondo Peninsula
EnergyZambales(Subic)

2012

Indicative(4) Quezon Power Expansion

500 MW

Quezon Power

Quezon2014

Indicative(5) Pagbilao Expansion

400 MW

Team Energy

Quezonn/a

Indicative

VISAYAS AREA:
1) 3 x 82 MW CFB Power Plant
Expansion

246 MW

Global Business
Power

Cebu

2010

Committed

2) 2 x 82 MW CFB Power Plant

164 MW

Global Business

Iloilo2010

Committed3) 1 x 100 MW CFB Power
Plant

100 MWDMCI Power

Iloilo2012

Indicative(4) 2 x 100 MW CFB Power
Plant

200 MW

KEPCO

Cebu

2011

Committed

MINDANAO AREA:(1) CFB Power Plant

200 MW

Conal Holdings

Saranggani

2012

Indicative

資料508

TOTAL

2,760 MW

Source: DOE

FUTURE MINE-MOUTH COAL POWER PLANT PROJECTSCAGAYAN2 x 50 MW (DMWAI)

ISABELA1 x 50 MW (PNOC-EC)

ANTIQUE1 x 100 MW (DMCI)SOUTH COTABATO/SULTAN KUDARAT
1 x 200 MW
資料509

2009 – 2014 COAL SUPPLY & DEMAND FORECAST(in MMMT @ 10,000 BTU/lb)
2009

2010

2011

2012

2013

2014

DEMANDPower generation
Industry

12.83
10.74
2.09

13.69
11.57
2.12

14.00
11.86
2.14

14.42
12.25
2.17

14.79
12.60
2.19

15.28
13.06
2.22

SUPPLY
Production
Importation

4.28
8.55

4.77
8.92

5.14
8.86

5.80
8.62

5.97
8.82

6.60
8.68

資料510

Source: 2007-2014 Phil. Energy Plan Update

CHALLENGES¾

Social acceptability for coal mining projects (Isabela,
Cagayan, Mindoro,etc.)¾

Environmental issues in coal mining and utilization¾

Development of untapped vast low-rank indigenous
coal resources¾

Most of existing coal-fired power plants are designed
for high-quality imported coal

資料511

ACTION PLAN TO ADDRESS THE CHALLENGES
¾

¾

¾

¾

¾

Information, Education and Communication campaign to explain
and promote coal exploration, development , production &utilization projects as sustainable and environmentally-soundundertakings
Adoption of Clean Coal Technologies in coal mining and utilization
Conduct of Philippine Energy Contracting Round to attract
investors in coal exploration, development and production
Promotion of low-rank coal resources for their development formine-mouth power plants using clean coal technologies
New coal-fired power plants should be designed for blended coal(high-quality imported coal and low-quality local coal)

資料512

資料513

(8)特別講演

資料514

Energy Policy for Climate Change
Mitigation
Jin-Gyu Oh(jgoh@keei.re.kr)

Korea Energy Economics Institute2009 APEC Clean Fossil Energy Technical andPolicy Seminar
Songdo Convensia, Inchecon, Korea
12~14 October 2009

資料515

1

Contents
 GHG emissions
 Projection of CO2 emissions to 2030
 Institutional framework
 Energy policies for climate mitigation

 Energy efficiency
 Low carbon energy mix

資料516

2

Korea at a Glance (2007)
z Energy Use– 242.9 million TOE– 96.6 % imported (81.9%)– Energy import bill:
US$ 95.0 billion (26.6%)– CO2: 532 million tCO2 (06)z Korea ranks– No. 10 in energy
consumption– No. 6 in oil consumption– No. 3 in oil imports– No. 2 in coal and LNG
imports– No. 10 in CO2z Land Area:– 99,392㎢ (S.Korea)
z Population:– 48.456 million persons
z Economy– GDP : US$ 971 billion– US$ 20,038 per capita– Trade : US$ 728 billion

資料517

3

GHG emissions by sector (2006)
Gross Emissions:
600 million tCO2 Eq

Uptake by Forest: 5.2%
Of Gross Emissions

Energy: Source of problem, but Solution
資料518

4

GHG Emissions by Gases (90-06)
Unit: million tCO2

CO2
CH4
N2O
HFCs
PFCs
SF6
Total

1990

2000

2005

2006

257.7

466.3

525.1

532.2

(86.4)
36.6(12.3)
2.9
(1.0)
1.0
(0.3)

(87.8)
28.0
(5.3)
14.4
(2.7)
8.3
(1.6)
2.3
(0.4)
11.7
(2.2)
531.0
(100.0)(88.3)
25.2
(4.2)
18.0
(3.0)
6.5
(1.1)
2.9
(0.5)
16.7
(2.8)
594.4
(100.0)(88.8)
25.3
(4.2)
15.5
(2.6)
5.9
(1.0)
2.9
(0.5)
17.8
(3.0)
599.5
(100.0)

n.a.
n.a.
298.1
(100.0)’90~06 (%)
4.6
-2.3
11.1
11.8
11.5
11.0
4.5

 CO2: Most important CH4: Ð: 12.3  5.3  4.2%
 New gases: 4.5%, increase in share
資料519

5

Energy related CO2 Emissions (90-06)

Unit: million tCO2

1990

2000

2005

2006

’90~06 (%)

CO2 (A)(mil. tCO2)

239.0

432.2

490.5

497.1

4.7

Population(thousand)

42,86947,00848,13848,297

0.7

Energy (B)(thousand toe)

93,192

192,887

228,622233,372

5.9

GDP (C)(2000, trillion KRW)

321

579

723

760

5.5

Per capita CO2
emissions (ton)

5.57

9.19

10.19

10.29

3.9

Carbon intensity over
Energy(ton/toe) (A/B)

2.56

2.24

2.15

2.13

-1.2

Energy intensity overGDP(toe/m. KRW) (A/C)

0.29

0.33

0.32

0.31

0.3

 Energy related CO2: 497 mtCO2, 93.4% CO2, 82.9% of total GHG (’06)
資料520

6

Indicators of Energy related CO2 (90-06)
2.50
2.37

2.08

1.13

資料521

7

Projection of CO2 by 2030: Assumption

Main drivers for energy demand and CO2 emissions
1990-05

05-10

10-20

20-30

05-30

5.5

4.7

4.0

3.5

3.0

2005

2020

2030

’05-03(%)

Pop (mil)

48.3

49.96

49.33

0.1

Vehicle (mil)

10.8

19.5

20.1

2.5

Person perhousehold

3.06

2.68

-0.53

GDP (%)

Floor space

5.4

9 Share of energy intensive industry (Petrochemical, non-metallic
mineral, primary metal) decrease 26.6% (2005)  19.5% (2020)  17.3% (2030)

資料522

8

Projection of Energy by 2030(%)
'05~'10 '10~'20 '20~'30 '05~'30

2005

2010

2020

2030

Primary energy(million TOE)

229.3

261.5

328.8

400.1

2.7

2.3

2.0

2.3

Per capita energy(TOE/person)

4.75

5.31

6.58

8.11

2.3

2.2

2.1

2.2

0.32

0.29

0.24

0.21

-2.0

-1.6

-1.5

-1.7

0.57

0.58

0.57

0.57

Energy/GDP(TOE/KRW mil.)Energy-GDP
elasticity

1.37 (90-97), 0.76 (08-05)

 Energy Consumption Growth for 2005-2030: 2.3%
 Energy Intensity Declines by 1.7% p.a.
• Improvement in Energy Efficiency• Shift of Economic Structure toward Less Energy-Intensive Industries
資料523

9

Projection of CO2 by 2030
CO2 emissions(million TCO2)
Per capita CO2(TCO2/person)
CO2/GDP(TCO2/KRW mil.)
CO2/Energy(TCO2/TOE)
CO2 ･GDP
elasticity

(%)

2005

2010

2020

2030

500

568

676

790

2.6

1.8

1.6

1.8

10.3

11.5

13.5

16.0

2.2

1.6

1.7

1.8

0.70

0.62

0.51

0.40

-2.1

-2.1

-1.9

-2.1

2.18

2.17

2.06

1.97

-0.1

-0.5

-0.4

-0.4

0.54

0.44

0.45

0.47

-

1.20
- (90-97), 0.66
- (08-05) -'05~'10 '10~'20 '20~'30 '05~'30

 Energy related CO2 Growth for 2005-2030: 1.8%
 Carbon Intensity Declines by 2.1% p.a.
• Improvement in Energy Efficiency• Energy Mix

資料524

10

Institutional Framework for
Climate Mitigation Energy Policy Inter-Ministrial Committee on UNFCCC

 Chaired by Prime minister Established in1998
 Adopted 1 (1999), 2, 3 (2005),4th (2007)‘Comprehensive National
Action Plan on Climate Change’.
 Establishment of Presidential Committee on Green Growth (2.16, 09) Combine Committee on CC, Committee on Sustainable Development,
Energy Council (chaired by President) Tackle climate change, sustainable development, energy, green growth Basic Law on Green Growth: submitted to Parliament (2.09)

資料525

11

Framework: Low carbon, Green growth Presidential Committee on Green Growth adopted (6 July,2009) National Strategies for Low carbon, Green growth The Five year National Plan for Low carbon, Green growth 3 Themes, 10 actions
Objectiv Low Carbon Society /Energy Securityes
Build a low carbon
society
Greater energy
security
Addressing climatechange

New Engine for Growth

Enhanced Quality of Life &International Leadership

R&D for green
Green transportation /technology
land management
Foster green industry
Green lifestyle
Fostering international
Greening industry
leadership
Laying foundationsuch as tax system
資料526

12

Energy Policies for
Climate Mitigation

資料527

13

Energy Policies for Climate Mitigation
 4th National Basic Plan for rational use of energy

 Runs from 2008-2012
 Embodied in National Strategies, 5 Year Plan Setting target for energy efficiency improvement• E/GDP decrease by 11.3% for 5 years, 23.5%(07-17), 44.8%(07-30)

 Low carbon Energy Mix• New and renewable energy• Nuclear Growth of New green industry

資料528

14

Energy Policies for Climate Mitigation
 industry sector• VA for general industry: partnership program between thegovernment and industry, provided with low-interest loans, tax
credits, and technical support. 74 percent (1,383 firms). will
expand VA to NA (negotiated agreement).
• Industrial energy audit: manufacturers consuming more than
2,000 TOE are mandated• Promotion of Energy Service Company (ESCO): investment inlighting -> process improvements and waste heat utilization.
third-party financing.
• Demand Side Management (DSM) program: electricity companies,
gas companies, and district heating companies

資料529

15

Energy Policies for Climate Mitigation
 transportation sector• Improvement of fuel economy of vehicles: fuel-efficiency rating
and labeling program, expand coverage– 12.4 km/liter to 14.5 km by 2012 (small automobiles)– 9.6 km to 11.2 km (16.5 % increase) (larger cars)• Promotion of small car use: 800cc, tax exemptions, tax
deductions, and parking and toll fee discounts• Promotion of hybrid car: strong promotion, excise tax deduction
and registration fee exemptions• Promotion of bicycle use: build a 9,170 km bicycle-only road
• Promotion of mass transit system: bus-only lanes in the major
metropolitan areas
資料530

16

Energy Policies for Climate Mitigation
 commercial and residential sector• Management of energy-intensive buildings: 148 buildings• Promotion of high-efficiency household appliances: CO2 emission
labeling for 17 home appliances in addition to energy
efficiency labeling, minimum energy performance standards

資料531

17

Energy Policies for Climate Mitigation
 Low carbon program in the electricity sector

 installed capacity of 73 gigawatts (GW) Generation currently• nuclear power (39%), coal (37%), LNG (18%), oil (4%), hydro(1.4%) in 2006
• Coal (39%), nuclear power (34%), LNG (22%), oil (2%) in 2008

 Future expansion from 71.4 GW in 2008 to 100.9 GW by
2022 (additional generation capacity of 29.5 GW)• Electiricity demand increase 2.1% per annum to 2022 (15 years)

資料532

18

Energy Policies for Climate Mitigation
 Low carbon program in the electricity sector

 increase the share of nuclear, decrease coal power 12 new nuclear power plants (currently, 20 units with 17.72
GW), 11 units of LNG power plants (currently, 46 units), 7
units of coal power (currently, 49 units)• nuclear, coal, and LNG power plants: 24.8%, 33.2%, 25.2% (2008)• nuclear, coal, and LNG power plants: 32.6%, 29.2%, 22.9% (2022)• power generation, nuclear power increase: 34%(08) to 48% (2022)

 demand side management programs: reduce peak load by
11.2 percent in 2022

資料533

19

Energy Policies for Climate Mitigation
 Low carbon program in new/ renewable energy Currently very low 2.4% (2007) including large hydro Ambitious target: 4.3% (2015), 6.1% (2020), 11%(2030)
 FIT (feed-in tariff) RPS (renewable portfolio standard), 2012
• 3% of electricity production• 3% biodiesel for transportation fuel

 Deployment of 1million‘Green Homes’– Utilize Photovoltaic, Geothermal, Wood pellet, Small-scale Wind Power mandatory NRE use in Public Buildings newly constructed:
5% of Total Energy

資料534

20

Energy Policies for Climate Mitigation
 Low carbon program in new/ renewable energy• (Wind) Develop and Deploy Ocean Wind• (Tidal) Increase Deployment of Tidal /Tidal current Power– Siwha Lake, Garorim Bay, Uldolmok, etc.

• (Bio) Assist Development of Domestic, International Resources

資料535

21

New/ renewable energy
 Low carbon program in new/ renewable energy
2008

2015

2020

2030

%

63
(0.5)
313
(2.7)
1,084
(9.2)
2,210
(18.8)
1,071
(9.1)
280
(2.4)
393
(3.3)
6,316
(53.8)

342
(2.0)
552
(3.2)
2,035
(11.6)
4,211(24.0)
1,165
(6.6)
544
(3.1)
907
(5.2)
7,764
(44.3)

1,882
(5.7)
1,364
(4.1)
4,155
(12.6)
10,357(31.4)
1,447
(4.4)
1,261
(3.8)
1,540
(4.7)
11,021(33.4)

20.2

Waste

33
(0.5)
59
(0.9)
106
(1.7)
518
(8.1)
946
(14.9)
9
(0.1)
0
(0.0)
4,688
(73.7)

Total

6,360

11,731

17,52033,027

Target in primaryenergy

2.58%

4.33%

6.08%

11.0%

Solar thermal
Photovoltaic
Wind
Biomass
Hydro
Geothermal
Ocean

15.3
18.1
14.6
1.9
25.5
49.6
4.0
7.8

資料536

22

Thank you for attention

資料537

23

2009 APEC Clean Fossil Energy Technical and Policy Seminar

Obstacles and Path for Actual
Implementation of CCT in Korea
2009. 10. 13.
Songdo Convensia, Incheon
Yongseung Yun
Plant Engineering Center, Institute for Advanced Engineering
Republic of Korea
資料538

Background Power plant sector consumes 38% of total fuel, comprises
28% of CO2 emission in Korea.
 It appears imperative to utilize CCT in Korea because Korea
imports 97% of energy and minimum 29-32% of electricity
should come from imported coal.
 CCT power plants has been included in the long-term
electricity forecast plan from 1998.
 Plan in installing CCT plants had been rescheduled threetimes from three plants of 300 MW by 2007, 2013, 2014 to
one CCT plant by 2009, and finally one CCT plant by 2013.
 At the beginning for the CCT technology, IGCC and PFBC
have been considered and IGCC was chosen.
 One 300 MW size IGCC plant based upon Shell gasification
technology is scheduled to operate from 2013 or after.
2
資料539

Long-term Electricity Generation Capacity by Energy
Source in Korea
Installed Capacity (MW)

Oil
LNG
Coal

Nuclear

資料540
thSource: “4 Basic Plan for Electricity Supply and Demand,” MOCIE, 2008. 12.

Year

Long-term Power Plant Capacity by Energy Source

Fuel Source

NuclearCoal

LNG

Petroleu
Othersm

Current Capacity,
17,720 23,710 17,970
5,340
MW(20 units) (49 units) (46기)(27기)(End of 2008)
Planned Capacity,
15,200
6,240
6,630
70
MW
(12 units) (7 units) (11 units) (1 unit)(2009~2022)
Disused Capacity,
530
1,540
1,820
MW
(3 units) (6 units) (13 units)(2009~2022)
Total Capacity,
32,920 29,420 23,060
3,590
MW(32 units) (53 units)(51 units) (15 units)(Year 2022 basis)

6,640

5,270
-

Sum
71,36033,4103,880

11,900 100,890

 There is a potential CCT market of 6,770 MW in Korea by 2022.
資料541
thSource: “4 Basic Plan for Electricity Supply and Demand,” MOCIE, 2008. 12.

Installed and Actual Electricity Generation by Energy Source

LNG

Petroleum

Hydro

OthersSum

17,716 23,705 17,969(24.8) (33.2) (25.2)

5,340
(7.5)

3,900
(5.5)

2,734
(3.8)

71,364(100)2015 25,916 29,420 23,062(27.7) (31.4) (24.6)

4,291
(4.6)

4,700
(5.0)

6,179
(6.6)

93,568(100)2022 32,916 29,420 23,062(32.6) (29.2) (22.9)

3,591
(3.6)

4,060
(4.7)

7,202
(7.1)

100,891(100)

Energy Source Nuclear
2008
Installed
Capacity(㎿)

Actual2008
Electricity
2015
Generatio
n
2022
(%)

Coal

34.0

39.3

21.7

1.9

0.4

2.7

100

38.6

39.9

12.9

0.2

0.6

7.8

100

47.9

36.0

6.2

0.2

1.3

8.4

100

資料542
th
Source: “4 Basic Plan for Electricity Supply and Demand,” MOCIE, 2008. 12.

Capital Cost for IGCC, What will be actual cost?

(Source: "Increasing Costs in Electric Markets," US Federal Energy Regulatory Commission, 2008. 6. 19.)

 CCT requires some kind of governmental support.
 For using public money, a clear picture regarding total
cost should be readily available.
 Current situation is quite murky, enough to give asuspicious impression to stakeholders.
資料543

Plant Availability, Can we rely on somebody?

Source: Steve Jenkins, “Fundamentals of
Gasification,” 2007 Gasification
Technologies Workshop, Denver, USA,2007/3/14.

 Demo plants show 4-5 years of trial and error, still
no clear picture on >90% availability.
 Technology masters are not in sight, only sellers.
 Will it be better in the near future? Possibly.
資料544

Position of CCT in Korea
 Construction plan for CCT has postponed after the first CCT
construction plan in the long-term power plant construction
schedule in 1998, in that 300 MW CCT startup wasscheduled by 2005.
 The CCT plan was rescheduled in 2000 to the plan of three
300 MW CCT plants by 2007, 2013, and 2014.
 In August, 2002, only one 300 MW CCT plant is included tostart operation by 2009.
 Contrast to the coal-based IGCC, two petroleum refineries
in Korea finished feasibility studies regarding the 300-600
MW residual oil based IGCC plants and wait more favorable
situation.
 Korea includes electricity from coal and petroleum residues
gasification as a new energy category, which means that
IGCC is entitled for incentives in electricity price.
資料545

8

Position of Power Companies
 Since separate power companies are competing for cheap
electricity after the deregulation in 2001, power companies
are becoming more concerned with mature and proventechnology as well as cheap feedstock.
 Private companies are also able to participate in theelectricity market in Korea after the deregulation in 2001.
 Fossil fuel based power companies prefer coal as a main
feedstock of base load for electricity generation with natural
gas power plants as a backup for load changing period,
while the. private companies favor natural gas for power
generation
 With new stringent NOx control from 2005, powercompanies in Korea prefer installing additional de-NOxfacilities instead of venturing into new technology like IGCC.
資料546

9

Obstacles for CCT Introduction in Korea- Power Companies Conception  Deregulation of power company Æ Prefer short-term profit.
 Hesitance of accepting the new technology, especiallygasification, and concerns on technical complexity anddealing with explosive gases, by people in power industry.
 Environmental advantages of IGCC have been widely
accepted. But, environmental regulation is not strong
enough yet to justify new technology. Wait and see trend.
 With introduction of RPS (Renewable Portfolio Standard) from2013, power companies are beginning to be serious on
new electricity sources, including IGCC.
 Reports of less satisfactory performance in demonstration
CCT plants and still expensive capital cost.
9 High technological and economical risks by low availability

and reliability
資料547

10

Obstacles for CCT Introduction in Korea- People & NGO’s Conception -Strong position of NGO’s on reducing fossil fuelusage, no matter what.
9 NGO’s continuous insistence that energy policy

should be switched into encouraging the energy
system based on pure renewables that should
replace fossil based energy infrastructure.
9 NGO’s persistent push to delete any energy fromfossil fuels from the list of new energy category
even with clear environmental advantages by CCT
can influence the actual CCT implementation.

People’s perception on coal as “dirty” reinforcedby the notion as a main culprit for CO2 emission
資料548

11

Aspects to Consider and Suggestions
 Difficulty in decision making for the construction cost of US$ 0.4-0.8
billion without clear picture on ROI.
 No clear decision is possible for the power company in constructing CCT
plant when there is no legal obligation to fulfill a portion of new andrenewable energy in RPS system.
 Environmental regulation level is still not stringent enough to giveleverage to CCT plants. Current conventional facilities are still usablewith small modification to meet the environmental standards. Thus,
incentives are still not present to overcome the high risk in construction
and operation.
 Deregulated power companies prefer natural gas power plants for theirshort-term profit. Therefore, government support should be considered.
 Local manufacturing capability is not sufficient. With local manufacturingof key CCT components, total investment amount can be lowered andgovernment subsidy, if there’s any, might be justified.
 Requires more wide distribution of information on the current status on
CCT technology and cost.
資料549

Future Path for CCT in Korea
Eventual construction of a commercial CCT plant of 300 MW
appears to be realized after 2013.
More stringent environmental and CO2 regulation might
increase the momentum for the CCT power plants in Korea.
Realizing higher plant availability and lower cost is a key
factor.
Need to improve local manufacturing capability to lower thecost.
Dissemination of information on the role of coal as aninevitable energy source and that coal can be utilized
eventually as clean as natural gas with currently developing
CCT are in progress.
- http://www.coal.or.kr- http://www.igcc.or.kr
資料550

Conclusions
 In the long run, it appears imperative to utilize CCT technology in
Korea because Korea imports 97% of energy with the requirement ofenergy diversification and minimum 29-32% of electricity should comefrom imported coal.
 However, there exist many obstacles in introducing CCT into Korea
such as serious concerns for the commercial status of the technology
itself and the reported low availability performance from thedemonstration plants.
 Construction of one 300 MW IGCC plant in Korea and operation from2013 will lay out a solid foundation for active CCT projects.
 Government incentives appear to be essential to introduce CCT in
Korea.
9 Even much smaller incentive in electricity price than solar and wind can push the inertia for the
early CCT introduction in Korea.

 With close cooperation on CCT among interest-sharing countries andprivate sector would enhance the possibility in further CCT
implementation of commercial scale in Korea.
資料551

(9)セッション 5

資料552

2009 APEC Clean Fossil Energy Technical and Policy Seminar

資料553

Contents

資料554

Energy Supply(2008)••

Energy Imports(Billion $)142- Crude Oil

86- Refinery production

22- Coal

13

- LNG

20

- Nuclear1

Dependency on imports of Energy : 97% (as of 2008)
More than 86% of oil from Middle East (as of 2008)
資料555

3

Primary Energy Consumption(2008)
EnergyConsumption(million TOE)

239

- Coal

66

- Oil

100

- LNG

35

- Hydro1- Nuclear

32- Other5

1995-2005

Korea

Germany

U.K.

Japan

U.S.

Average Growth Rate ofEnergy Consumption(%)

4.22

△0.28

0.57

0.66

0.97

資料556

4

Final Energy Consumption(2008)(million TOE)

(million TOE)

Industry

Transport

Other sectors

Coal

Oil

Gas

107

35

41

26

97

19

資料557

5

Electricity Others
33

7Power Plants and Real Power Generation(2008)(billion kWh)
Hydro

Coal

Oil

Gas

Nuclear

Others

Total

6

174

15

76

151

1

423

資料558

6

CO2 Emission(2006)
100

USA

million tCO2
5,697

80

China

5,607

60

Russia

1,587

40

India

1,249

20

Japan

1,213

0

German824

Canada

539

UK

537

Korea

476

CO2 Emission Increase Rate(%)-20

USA(2) Aus(16)

-40

Canad
a(11.4)
Russia(-22.5)Germany(-15.5)Japan(11.1)

Korea(82.4)Englan(-4.9)* 6 Greenhouse gases
CO2

CH4

N 2O

HFCs

PFCs

SF6

423(88.8%)20(4.2%)12(2.6%)5(1%)

2(0.5%)

10(3%)

資料559

7

Contents

資料560

Energy Technology R&D• R&D budget has increased more than 10 times since 2000.
(‘00) 53 million $(‘08) 626 million $- A large sum of investment in the development of NRE technology.
Million US$
7,000

626

6,000

521

5,000

414

4,000

327

3,000

197

2,000
1,000
-

7
1992

1993

Electric Power

1994

38

32

22
1995

1996

1997

1998

1999

53

70

2000

2001

New & Renewable Energy
資料561

9

253

118

2002

2003

2004

2005

2006

2007

2008

Energy Efficiency and Resources

Energy Efficiency & Resources
차세대 Capture태양광 발전
Carbon& Storage수소·연료전지
실용화
EnergyEfficiency

z Innovative materials : nano technology
z Energy Storagez Building Efficiency

Resources Technology

z Pre-Combustion Technology
z Post-Combustion Technology
z Oxyfuel Combustion Technology

차세대Energy
청정연료Sources
기술
Clean

z Minerals and Materials Processingz Petroleum Resourcesz Geology & Geo informationz GTL, CTLz BTLz Gas hydrate

資料562

10

Electric & Nuclear Power Technology
수소·연료전지
실용화
Clean
Coal Technology차세대 태양광
발전
Transmission
andDistribution
z Superconductivityz Advanced transmission
and distributionz Efficient power devices

z Advanced Power Generationz Power Equipment Efficiency
z USC, IGCC

Power System

차세대
청정연료
기술
NuclearPowerz Smart Gridz Power Demand Control Systemz Policyz Advanced Nuclear Powerz High-level waste disposalz Component Development

資料563

11

New & Renewable Energy Technology차세대 태양광 발전
Photovoltaics

수소·연료전지
실용화
Hydrogen& FuelCells
z Hydrogen Production

z Electronic Materials and Devices
z Crystalline Si PV
z Si thin-film, CIGSz Dye-sensitized, Organic PV
z Silicon Materials and devicesz Hydrogen Deliveryz Hydrogen Storagez Fuel Cells(PEMFC, MCFC, SOFC)

Wind Power차세대 청정연료
기술
ThermalEnergy Sourcesz Large Scale Wind Powerz Biomassz Onshore Wind Powerz Geothermalz Offshore Wind Powerz Solar Heatingz Advanced Blade Technology
資料564

12

Green growth is a “new National Development paradigm” that creates new growth[President Lee’s 8.15 Liberation day celebration speech]
engines and jobs
Promotion of green energy industry as a core growth engine of green growth[Aug 27th, The 1st National Energy Master Plan]

Increase
Self-sufficiency
Raise the use of New
and Renewable
EnergyInvest in
Energy Technology• 18% by 2013
• 40% by 2030

• 11% by 2030
• ‘Green Home’Project• Increase R&D investment• Produce ‘Green Cars’
資料565

13

Low Carbon Society

Energy15 Green Energy Technology

Market AttractivenessTechnical Importancez Market Potential
z Contribution to the environment( CO2 Reduction)z Competitiveness in global marketz Technical Innovationz Technology Development Capacity
z Need for government support

StrategyRoadmap

Early
Development

PV, Wind Power, LED, Smart Grid, Green Cars, Heat
Pump , Energy Efficient Building, Nuclear Power , CHP

Nextgeneration
development

Fuel Cells, IGCC, Energy Storage, Clean
Fuels, CCS, Superconductivity
資料566

14

Contents

資料567

3 Government Ministries• 3 government ministries are involving CCS R&D
project– MKE (Ministry of Knowledge Economy)– MEST (Ministry of Education, Science & Technology)– MLTM (Ministry of Land, Transport & Maritime Affairs)• 2008 Budget
MKE

MEST

MLTM

12.5 million$

6.4 million$

2.5 million$

資料568

16

CO2 Absorption••

Supported by MKE,MEST
developed since 1994

Target: Capture Cost: 55 $/tCO2 → <30$/tCO2
Application: PC
50 tCO2/d DEMO (’08 – ’14)
資料569

17

Test Bed of CO2 Capture
at Seoul LNG Cogeneration Plant,
2tCO2/dDry Sorbent Technology
Completing Pilot scale test, 2000 Nm3/h(2012: < 17 US$/tCO2)
2008
100 Nm3/h process development
Development of Commercial level sorbent
2005

2 Nm3/h process test facility
Met the target performances of sorbent in the Lab
100 Nm3/h test facility
at KIER(2006)••

Sorb KX 40

Supported by MKE, MEST
developed since 1994
資料570

18

Sorb TKX 35

Oxy-fuel Combustion for PC Power Plant• Supported by MKE (ETI/KEMCO)• Period: 2007 ~ 2015
• Investment: $50 million total• Target: 100 MWe Oxy-fuel PC boiler development• Will be applied to Youngdong power plant

Phase 1(2007-9)

Phase 2(2010-12)

Phase 3(2013-15)

Research andConceptual design

Basic/Detailed
Design of Demo

Construction of
Demo Plant

資料571

19

IGCC+CCS• IGCC demonstration project was launched in 2006 supported
by MKE• Overview
9 Size: 300 MWe, Efficiency: over 42% (HHV)
9 NOx: under 30 ppm, SOx: under 15 ppm• Time Schedule
9 2006-2009: Development of key technology; Design of demo plant
9 2010-2012: Construction of IGCC demo plant
9 2013-2014: Operation & Improvement of demo plant• CCS in IGCC program has been launched in Sep. 2008 supported
by MKE.
資料572

20

Storage

Ref. S. Bachu, 2007, Capacity Building Workshop, Pittsburgh
資料573

21

International Cooperation• CSLF (Carbon Sequestration Leadership Forum)
9 Framework for international cooperation in research and development
for the separation, capture, transportation and storage of CO2• IEA GHG (Greenhouse Gas), IEA CCC, IEA FBC• APP (Asia Pacific Partnership on Clean Development & Climate)
9 In APP, Korea is actively involved in Cleaner Fossil Energy, that is
CCS area.
9 Korea has been appointed chairs of Renewable Energy area,
Buildings & Appliances area.
• FutureGen
9 Korea joined in Government steering committee.
資料574

22

Contents

資料575

CCS Challenges in Korea• Need significant reduction of CO2 capture cost from new
improved methods• Need to drive capture cost down from 45 $/tCO2
to <30 $/tCO2• Need R&DD for a zero emission coal power generation• Need to confirm the capacity of storage and to overcome
the shortage of storage sites• Need economic incentives, legal frameworks, favorable
public perception in the medium and longer term
資料576

24

Accelerating CCS R&DD

• Fossil energy is still very important at present and in
future, and is a base of energy resources in Korea.
• Korean government has put high emphasis on R&D ofcarbon capture technologies and continues its support.
• International cooperation will be an effective way for CCS
and clean coal technology .

資料577

25

資料578Mixed Gas
StreamMostly CO2

CO2
and othergases
Mostly H2Update on U.S. DOE’s Sequestration Program
Scott M. Smouse
Senior International Manager / Strategic Center for Coalscott.smouse@netl.doe.gov 412-386-5725

APEC EGCFE Clean Fossil Energy Technical and Policy Seminar
Incheon, Korea
12-14 October 2009
資料579
October 2008

Carbon Sequestration Program Goals
Develop Technology Options That...
• Deliver technologies and best practices that provide Carbon Captureand Safe Storage (CCSS) with:– 90% CO2 capture at source– 99% storage permanence– < 10% increase in COE• Pre-combustion capture (IGCC)– < 35% increase in COE• Post-combustion capture• Oxy-combustion

2

資料580

Key Challenges to Carbon Capture and Storage
Technical Issues

Legal/Social Issues• Capture Technology– Existing Plants– New Plants (PC)
– IGCC• Regulatory Framework– Permitting– Treatment of CO2• Infrastructure• Cost of CCS• Sufficient Storage Capacity• Permanence• Best Practices– Storage Site
Characterization– Monitoring/Verification– Site Closure– Etc.
3• Human Capital• Legal Framework– Liability– Ownership• pore space• CO2• Public Acceptance(NIMBY Æ NUMBY)

Projects helping to address
both categories of issues
資料581

U.S. DEPARTMENT OF ENERGY • OFFICE OF FOSSIL ENERGYNATIONAL ENERGY TECHNOLOGY LABORATORYCARBON SEQUESTRATION PROGRAM
Core R&D
CaptureTechnology
SolutionsGeologic Storage

Benefits

4

Technology
SolutionsNorth America Energy
Working Group
Carbon Sequestration
Leadership Forum

Validation

Simulation andRisk Assessment• Reduced cost of CCS• Tool development for risk
assessment and mitigation• Accuracy/monitoring quantified• Capacity validation• Indirect storage

Regional Carbon Sequestration
Partnerships
Characterization

Monitoring, Verification,
and Accounting (MVA)

CO2 Use/Reuse

GlobalCollaborations

InfrastructureInternational
Demonstration Projects

Development

Lessons
Learned

Other Large-Scale Projects

Lessons
LearnedBenefits• Human capital• Stakeholder networking• Regulatory policy development• Visualization knowledge center• Best practices• Public outreach and education

Demonstration and Commercialization
Carbon Capture andSequestration (CCS)
資料582

Asian-PacificPartnership (APP)

Benefits• Knowledge building• Project development• Collaborative international
knowledge• Capacity/model validation• CCS commercial deployment

Strong industry support~ 39% cost share on projects

180
160
140
120
100
80
60
40
20
0

Federal investment to date
~ $631 million

10 09
Re
q

08

20

20

07

20

06

20

05

20

04

20

03

20

02

20

20

01

00

20

99

20

19

19

19

98

Budget Breakdown97

DOE Budget (Million $)Sequestration Program Statistics FY2009

Fiscal Year

Diverse research portfolio~ 80 Active R&D Projects

Simulation and
CO2 Use/Reuse
Risk
5%
Assessment
MVA
6%
10%

Geologic
CarbonSequestration
5%
CO2 Capture
14%

5

資料583

Regional
Partnerships
60%Core R&D Focus Areas
andSupporting Research Pathways
Geologic Carbon
CapturePre-combustion(Pre-Combustion)
CaptureMembrane Processes
Membrane Solvent-Based Processes

Sorbent-Based Processes
Solvent-Based Improved Water Gas Shift Sorbent-Based
Reactor Coal-to-Liquids Technology

Novel
Concepts
Novel Concepts

MVA

Geologic Carbon

Storage
Storage

 Improved Fundamental
 Improved
Fundamental
Understanding
Understanding
Technology Development


MVA


 Atmospheric andRemote Sensing Near-Surface Monitoring Wellbore Monitoring Subsurface Monitoring Accounting Protocols

 Technology
Development

Simulation andRisk Assessment

CO2 Use/Re-use
Approaches
Approaches

 Conversion
CO CO2
 Conversion ofof
Storage Non-Geologic CO CO Non-Geologic
2
Indirect Storage
Storage Beneficial Use of Produced
 Indirect
Water Storage
Concepts
 BreakthroughUseof Beneficial
Produced Water
 BreakthroughConcepts
2

2

6

資料584

 Mathematical Models
Development
and Verification

Risk Assessment

 Improved Risk
Assessment
Protocols
Key:

Focus Area
 Research Pathway

Regional Carbon Sequestration Partnerships• Engage regional, state, and local governments• Determine regional sequestration benefits• Baseline region for sources and sinks• Establish monitoring and verification protocols• Address regulatory, environmental, and outreach issues• Validate sequestration technology and infrastructure• 7 Regional Partnerships• 43 States, 4 Canadian Provinces• 350+ distinct organizations

Developing the Infrastructure for Wide-Scale Deployment
7

資料585

Regional Carbon Sequestration Partnerships
Program Phases
FISCAL YEAR
2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017
CHARACTERIZATIONCHARACTERIZATION
PHASE
PHASE
Characterize
Characterize
allallRCSP
RCSP
regionsregionsfor
forcarbon
carboncapture
captureandandstorage
storageopportunities
opportunities$16M DOE + $5M CS
VALIDATION PHASE
Validate technologies throughValidate
technologies
field
testing
at selectedthroughgeologic
field andtestingatselectedgeologic andterrestrial site locations
terrestrial site locations

Scale of 100 to
10,000 Tons CO2$120M DOE + $43M CS

Scale of 1M Tons CO2

DEVELOPMENTPHASE
DEPLOYMENT
PHASEdevelopment
Complete
Completelargelarge-volume-volumedeploymenttests
testsofofsequestration
sequestrationtechnologies
technologies
thatwillwill
help
enablefuturecommercial--scalescale
applications
that
help
enablefuturecommercial
applications~$500M DOE - over $200M cost-share

8

資料586

Updated National Atlas Highlights (Atlas II)
Adequate Storage Projected for the North America
Annual Point Source CO2 Emissions ~3.8 GT
U.S. Emissions ~ 6 GT CO2/yr all sources

Oil and Gas Fields

Conservative
Resource
Assessment

Saline Formations

North American CO2 Storage Potential(Giga Tons)
Sink Type

Low

High

Saline Formations

3,300

12,600Unmineable Coal Seams

160

180

Oil and Gas Fields

140

140

Unmineable Coal Seams

Increases fromAtlas I
Hundreds ofYears of
Storage
Potential

Available for download at http://www.netl.doe.gov/technologies/carbon_seq/refshelf/atlasII/atlasII.pdf
9

資料587

RCSP Phase II: Validation
Small-Scale Geologic Field Tests
Saline formations(3,000 to 60,000 tons)
Depleted oil fields(50 to 500,000 tons)
Coal Seams(200 – 18,000 tons)
Basalt formation(1,000 tons)

11

RCSP
Big Sky

Saline 1
Oil-bearing
2

MGSC

3

4

5

Saline 6
Coal seam

PCOR

Saline
MRCSP

8

9

10

Oil-bearing

9
10

MGSC
6

WESTCARB
23

19
21

SWP

8

2 3
7 5
4
18

20

10
17

MRCSP

PCOR

11

12

Coal seam
13

17

Oil-bearing
14

SECARBSECARB14
15 16

Saline15

16

Coal seam
17

18

Oil-bearing
Injection Complete

19

SWP

Injection Ongoing

資料588
Data current as of April 2009

Coal seam
Salineto Phase III)
10

20

21

2009 Injection2010 Injection (Project moved

Illinois Basin

7

12

BSCSP

Geologic
Province
Columbia Basin

13

1

22

FormationType

WESTCARB

22

23

Cincinnati Arch,
Michigan Basin,
AppalachianBasin
Keg River,
Duperow,
Williston Basin
Gulf Coast,
Mississippi Salt
Basin, Central
Appalachian,Black Warrior
Basin
Paradox Basin,
Aneth Field,
Permian Basin,
San Juan Basin
Sacramento
Valley, Colorado
PlateauDevelopment Phase
Scaling Up Towards Commercialization
FISCAL YEAR
2008

2010

2012

STAGE1.1.
Stage
Site selection and characterization; Permitting
and NEPA compliance; Well completion andtesting; Infrastructure development

2014

2016

Scale up is required to provide insight
into operational and technical issues
that differ from formation to formation

Stage 2.2.
STAGE
CO2 procurement and transportation;
Injection operations; Monitoring activities

Stage 3.3.
STAGE
Site closure; Post-injection monitoring,
Project assessment

RCSP Deployment
DevelopmentPhase
Phase– 10 years+
years (FY2008-2017)(FY2008-2017+) -

11

2018

資料589

Development Phase Goals• Assess– Injectivity and Capacity– Storage Permanence– Areal Extent of Plume and Leakage
Pathways• Develop– Risk Assessment Strategies– Best Practices for Industry• Engage in Public Outreach and
Education• Support Regulatory Development
12

資料590

RCSP Phase III: Development
5Core Sampling
Taken

Large-Volume Geologic Field Tests
Injection
Well Drilled

4
1

3

2

8

9 Nine large-volume tests
9 Injections initiated 2009 – 2011

9

6

Partnership1

Big Sky

2

MGSC

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

3

MRCSP

Shallow Mt. Simon Sandstone

SalineWilliston Basin Carbonates

Oil Bearing

Devonian Age Carbonate RockSalineLower Tuscaloosa Formation
Massive Sand Unit

Saline7

Injection
Started42009 Injection Scheduled2010 Injection Scheduled2011 Injection Scheduled

5

PCOR

6
7
8

SECARBSWP

9 WESTCARB
13

資料591

Regional Jurassic & Older
Formations
Central Valley

Type
SalineSalineSalineSalineCCS Best Practice Manuals
Critical Requirement For Significant Wide-Scale Deployment
Capturing Lessons Learned
Version 1(Phase II)

Version 2(Phase III)

Final Guidelines(Post Injection)

2009

2017

2020

Site Characterization

2010

2016

2020

Simulation and Risk Assessment

2010

2017

2020

Well Construction and Closure

2010

2017

2020

Regulatory Compliance

2010

2016

2020

Public Education

2009

2016

2020

Terrestrial Sequestration Practices

2010

2016 – Post MVA Phase III

Best Practice Manual
Monitoring, Verification, andAccounting

14

資料592

Recent Program Funding Opportunity
Announcements (FOAs)• Pre-Combustion Carbon Capture Technologies for CoalBased Gasification Plants– Funding Opportunity Announcement DE-PS26-08NT00699– 9 projects selected in June 2009 in 4 major categories:(1) high-temperature/high-pressure membranes(2) high-efficiency solvents(3) solid sorbents(4) novel concepts– ~$14.4M total award value over 3 years ($3.1M cost-share)– Project awards by end of FY09
– Techline at
http://www.netl.doe.gov/publications/press/2009/09036DOE_Awards_Carbon_Capture_Projects.html
15

資料593

Recent Program Funding Opportunity
Announcements (FOAs)• Innovative and Advanced Technologies and Protocols
for MVA, Simulation, and Risk Assessment in Geologic
Formations– Funding Opportunity Announcement DE-FOA00023– Released 18 February 2009; Closing Date 12 May 2009– 19 projects selected in 3 major categories(1) MVA of CO2 sequestration in geologic formations(2) simulating behavior of geologically sequesteredCO2(3) conducting risk assessments associated withgeologic CO2 sequestration activity– ~$34.7M total award value over 4 years ($8.1M costshare)– Awards anticipated in October 2009
16

資料594

American Recovery and Reinvestment Act(ARRA) Funding for CCS• Secretary Chu announced on 15 May 2009, that $2.4
billion from ARRA to expand and accelerate commercial
deployment of CCS technology– DOE posted Notices of Intent supporting• Clean Coal Power Initiative - $800 million• Industrial CCS projects - $1.52 billion• Geologic sequestration site characterization - $50
million• Geologic sequestration training and research - $20
million– Techline at
http://www.fossil.energy.gov/news/techlines/2009/09029DOE_Announces_Stimulus_Funding.html
17

資料595

American Recovery and Reinvestment Act(ARRA) Funding for CCS• Industrial Carbon Capture and Storage Technologies for
Coal-Based Gasification Plants– Funding Opportunity Announcement DE-FOA-0000015– 12 Phase I projects selected in September 2009 (~7 months)– ~$44.1M total award value• $21.6M ARRA; $22.5M cost-share– Winning projects subject to further competitive evaluationin 2010 after successful completion of Phase 1 activities– Projects that best demonstrate ability to address their
mission needs will receive additional ARRA funding fordesign, construction, and operation– Techline at
http://www.netl.doe.gov/publications/press/2009/09072DOE_Announces_Industrial_CCS.html
18

資料596

American Recovery and Reinvestment Act(ARRA) Funding for CCS• Recent Industrial CCS Projects Awards– Ramgen Power Systems, LLC in August 2009
• Scale up device that uses supersonic shockwaves tocompress CO2 for capture and storage ($20M)• TechLine at
http://www.netl.doe.gov/publications/press/2009/09055DOE_Announces_Ramgen_Power_Systems.html– Arizona Public Service in September 2009
• Expand existing industrial and innovative algae-based
reuse carbon mitigation project ($70.5M)• TechLine at
http://www.netl.doe.gov/publications/press/2009/09064APS_to_Scale_Up_CCS_Project.html
19

資料597

American Recovery and Reinvestment Act(ARRA) Funding for CCS• Regional Sequestration Technology Training Projects– Funding Opportunity Announcement DE-FOA-0000080– 7 projects selected in August 2009 in 5 activity areas(1) Implement Organized Sponsorship Development Program –development of self-sustained long-term technology program,without federal government support(2) Short Courses on CCS Technologies – work with experts to identify
and develop training materials for professionals(3) Regional Training—Outreach and Networking – conduct training on
CCS technologies(4) Perform Regional/Basin Technology Transfer Services – transfer
technology with various outreach materials and coordination ofregional/basin efforts(5) Plan and Manage Recipient’s Regional Program– ~$8.47M total award value over 3 years– Techline at
http://www.netl.doe.gov/publications/press/2009/09062DOE_Awards_CCS_Training_Projects.html
20

資料598

DOE’s Global CCS Demonstration Role on Five Continents
Select DOE Participation in International CO2 Storage Projects
Location
North America, Canada
Saskatchewan
Weyburn-Midale
North America,
Canada, Alberta
Zama oil field
North America,
Canada,British Columbia
Fort Nelson

Operations

U.S.
Involvement

1.8 Mt CO2/yr
commercial 2000

2000-2011

250,000 tons CO2,
90,000 tons H2S
demo

2005-2009> 1 Mt CO2/yr,
1.8 Mt acid gas/yrlarge-scale demo

Europe, North Sea,
NorwaySleipner

1 Mt CO2/yr
commercial 1996

Europe, Germany,
KetzinCO2SINK

60,000-90,000
tonnes CO2
demo 2008

Australia, Victoria
Otway Basin
Africa, Algeria
In Salah gas
Asia, China,
Ordos Basin
21

100,000 tonnes
CO2 demo 2008
1 Mt CO2/yr
commercial 2004
assessment phase
CCS

2009-2015

2002-20112007-20102005-20102005-20102008-TBD
資料599

Reservoir
oil field
carbonate
EOR
oil field
carbonate
EOR
salineformation

Operator/Lead

Int’l Recognition

Encana,ApacheIEA GHG R&D
Programme, CSLF

Apache(Reg. Part.)

CSLF

SpectraEnergy(Reg. Part.)

CSLF

marineStatoilHydrosandstone

IEA GHG R&D
Programme, CSLF,
EuropeanCommission
CSLF, European
Commission,
IEA GHG R&D
Programme

GeoForschungsZentrum,
salinesandstone Potsdam(GFZ)
gas field
CO2CRC
CSLF
sandstonegas field BP, Sonatrach, CSLF, European
sandstone Statoil Hydro
Commission
Ordos
Shenhua Coal
Basin

Visit Our Websites

Office of Fossil Energy
www.fe.doe.gov

NETL
www.netl.doe.gov
22

資料600

GLOBAL CCS INSTITUTEACCELERATING CCS
Overview of the Global CCS Institute
2009
資料601

WWW.GLOBALCCSINSTITUTE.COMGLOBAL CCS INSTITUTE

THE BASIC RATIONALE“We strongly support the recommendation that 20
large scale CCS demonstration projects need tobe launched globally by 2010, with a view tosupporting technology development and cost
reduction for the beginning of broad deployment of
CCS by 2020.”
G8 Statement of June 2008
資料602

1

GLOBAL CCS INSTITUTEA BOLD NEW INITIATIVE
Global CCS Institute objectives


Pivotal role in facilitating the development and deployment of commercial-scale CCS
projects

Advise on the technologies across the CCS landscapeExpert insight on the costs and benefits and operational and legislative requirements

Work collaboratively to build confidence in CCS and drive international momentum

 AIM: 20+ fully integrated industrial scale demonstration
projects by 2020

資料603

2

GLOBAL CCS INSTITUTE

THE INSTITUTE Announced by the Australian Government in September
2008 the Global CCS Institute was formally launched in
April 2009. Independent legal entity in July 2009.
 The Australian Government has committed up to
AUD$100 million annual funding.
 Objective is to accelerate the deployment of CCS

資料604

3

GLOBAL CCS INSTITUTE

THE INTERNATIONAL STATUS
WORLD LEADERS TAKE A GLOBAL VIEW

資料605

9th July 2009 - Global CCS Institute formally launched at the G8 /MEF Summit in Italy

4

GLOBAL CCS INSTITUTE

THE FUNDAMENTAL DRIVER
Climate Change: Global CO2 Projections

IPPCC AR4 Nov07

Need to peak at
2015
50-80% reductions
required at 2050

550
ppm

30

Desirable
reduction

450
ppm

20

65550
ppm

4-

450

3 - ppm

Further rises to 2300

Required
reduction

1000
ppm

ºC

2100 range

Business-as-usual
1000
ppm

40

Global Temperature Rise

Goal: A long term moderate stable CO2 concentration in the atmosphere

21IPCC* Scenarios
0 -1990

A 2004 View

2010

2020

A Climate Change Perspective OTTER 2nd May 2008 : 01/01/2007 P 7

2030

2040

2050
Source: WBCSD 2005

資料606

5

GLOBAL CCS INSTITUTE

THE IMPORTANCE OF CCS~20% of required CO2
reduction from CCS

A 2008 View
資料607

6

GLOBAL CCS INSTITUTEMEMBERSHIP AND SUPPORTKEY:
Legal Members
Foundation Members

The Government of Australia
The Emirate of Abu Dhabi
The Government of Canada
The Government of the Peoples Republic of China
European Commission
The Government of Egypt
The Government of the French Republic
The Government of Germany
The Government of India
The Government of Indonesia
The Government of Italy
The Government of JapanThe Government of the Republic of Korea
The Government of Malaysia
The Government of Mexico
The Government of Netherlands
The Government of New Zealand
The Government of Norway
The Government of Papua New Guinea
The Russian Federation
The Government of South Africa
The Government of Sweden
The Government of United Kingdom
The Government of the United States of America
The State Government of New South WalesThe State Government of Queensland
The State Government of South Australia
The State Government of Victoria
The State Government of Western Australia
Asian Development BankJapan Bank for International Cooperation

AECOM Australia Pty Ltd
AGR Field Operations
Alstom Power Ltd
Altona Energy PLC
AMEC Plc
Anglo American Services (UK) Limited
Anglo Coal Australia Pty Ltd
A.P. Moller – Maersk A/SARUP Pty Ltd
ASME-Australia
Aurecon Australia Pty Ltd
Aviva Corp.
Baker and McKenzie
Bechtel Power Corporation
BHP Billiton
Booz & Co.
BP Australia Pty Ltd
Calera Corporation
Calix Limited
Chevron Australia Pty Ltd
China Huaneng Group
Chiyoda Corporation
Clean Energy Systems Inc
ConocoPhillips
CO2 Solutions Inc.
Deacons
Doosan Babcock Energy Limited
Duke Energy
The Dow Chemical Company
Enbridge Inc
ENEL
Enviro-Energy International Holdings Limited
Ernst & Young
Exxon Mobil Australia Pty Ltd
General Electric International Inc
Golder Associates Pty Ltd
Greenhouse Gas Storage Solutions (GGSS)Halliburton
Hatch Associates Pty Ltd
Hitachi Limited
Honeywell Ltd
HTC Purenergy Inc
Hydrogen Energy International
Limited
資料608
INPEX Corporation

IHI CorporationJGC Corporation
KPMG
Korean Energy Power Company
L.E.K. Consulting
Liberty Resources
Macquarie Capital Advisers LtdMærsk Olie og Gas
MASDAR
Mitsubishi Corporation
Mitsui & Co Ltd
Nippon Steel Engineering Co. Ltd
Parsons Brinckerhoff Australia Pty Ltd
Peabody Pacific Pty Ltd
Powerspan Corp
Praxair Inc
PricewaterhouseCoopers
Process Group Pty Ltd
Ramgen Power Systems, LLC
ResourcesLaw International Associates Pty Ltd
Rio Tinto Ltd
Rolls-Royce
RWE Power AG
Samsung Techwin Co. Ltd
Santos Limited
Senergy Alternate Energy Ltd
Services Petroliers Schlumberger
Shell International Petroleum Company Ltd
Siemens Ltd
Sojitz Corporation
Solid Energy New Zealand Limited
Southern States Energy Board
StatoilHydro ASA
Strike Oil Limited
Sumitomo Corporation
Taisei Corporation
Toshiba Corporation
Total S.A.
Toyo Engineering Corporation
TRUenergy Development Pty Ltd
Uhde Shedden (Australia) Pty Ltd
Vattenfall Europe
Zerogen

7

GLOBAL CCS INSTITUTEMEMBERSHIP AND SUPPORTLEGAL MEMBERS: 90

WDS Limited
Woodside Energy Ltd
Worley Parsons Services Pty Ltd
Xstrata Coal Pty LtdZEEP Australia Pty Ltd
Australian Coal Association
British Geological Survey
Carbon Capture and Storage Association
Cooperative Research Centre for Greenhouse Gas Technologies (CO2CRC)
Commonwealth Scientific and Industrial Research Organisation (CSIRO)
demosEUROPA
Electric Power Research Institute (EPRI)
Energy Research Centre of the Netherlands (ECN)
Fundación Ciudad de la Energía (Ciuden)
Główny Instytut Górnictwa
IEA Greenhouse Gas R&D ProgrammeJapan Coal Energy Center (JCOAL)
Lawrence Livermore National Laboratory
National Low Emissions Coal Research Ltd
Petroleum Technology Research Centre
Research Institute of Innovative Technology for the Earth (RITE)South African National Energy Research Institute (SANERI)
The Climate GroupThe Clinton Foundation
UCG Partnership
Underground Coal Gasification Association
United States Energy Association
University College London
World Coal Institute
Yonsei University
Zero Emission Resource Organisation

MEMBERS: 63
COLLABORATINGPARTICIPANTS: 3
TOTAL: 156
AS OF 9 OCTOBER 2009

Collaborating Participants:
International Energy Agency
International Energy Forum
The World Bank

資料609

8

GLOBAL CCS INSTITUTE

COUNTRY MEMBERSHIP

Member (includes European Commission)
Other countries engaged

資料610

9

GLOBAL CCS INSTITUTEBALANCE OF PARTICIPANTS
CO-OPERATING ORGANISATIONSThe Global CCS Instituteaims to maintain a balancein organisational, politicaland geographicalrepresentation –a true public private
partnership.

156 in total as of 7 October 2009
資料611

10

GLOBAL CCS INSTITUTE

ORGANISATION ASPECTS
Non Government Legal Entity
 Not-for-profit company limited by guarantee
 Initial skill-based board of directors•

Chair, Russell Higgins plus Tina McMecken and Makoto Akai

 International Advisory Panel of senior international advisors•

Chair, James Wolfensohn plus Nick Stern, Claude Mandil and Leena Srivastava Technical Advisory Committee for peer review/advice

Organisational aspects
 Head office in Australia (Canberra): 30 to 40 individuals including corporate
function Linkages/actions worldwide, to include:• Europe• North America• Asia
資料612

11

GLOBAL CCS INSTITUTE

THE WORK PLAN
LEADING THE WAY WITH VITAL PROJECTSThe Strategic Analysis of the Global Status of CCS
A comprehensive audit of the world’s current CCS projects to determine: Project status
 The costs involved
 The impact of the global financial crisis
 Policy and regulatory frameworks
 Research and development efforts
 Commercial and non-commercial gaps in the global deployment of CCS.

Portfolio of CCS Projects

A key portfolio will include a variety of CCS projects, spanning different technologies andgeographic regions, to deliver a comprehensive global approach.
A Rationale for Support

CCS ReadyA base line study to establish a clear definition of what it means to be ‘CCS Ready’
資料613

12

GLOBAL CCS INSTITUTE

THE WORK PLAN
FORGING PARTNERSHIPS, ENCOURAGING COLLABORATION

Project Support
 Direct financial project support

Knowledge sharing across international boundaries
 Development of an inclusive framework to build a global best practiceCommunity and public awareness action
 Support to international CCS Social Science Network over three years• Assessment of public awareness to date
• Analysis of local and global factors• Assessment of approaches, materials and efforts to engage effectively

 Development of material to inform at all levels

資料614

13

GLOBAL CCS INSTITUTECAPACITY BUILDING AND
STRATEGIC ALLIANCES
Capacity and capability building

Capacity building is a key activity to facilitate CCS deployment, both independently and in
partnership with other capacity building organisations
Focus will be on building capacity around project and commercial issues, regulatory and legal
frameworks, technical and financial issues

How do we best engage these particular countries?


Fund specific capacity building activities
Partnering with R&D and industry bodies
Partner with the Asia Development Bank

Strategic alliances

Establishing close collaborative partnerships with IEA, CSLF, World Bank, ADB, Clinton
Foundation and The Climate Group
Develop partnerships with other stakeholders to foster a co-ordinated approach

資料615

14

GLOBAL CCS INSTITUTESTRATEGIC ANALYSIS
WorleyParsons consortium engaged
over five months to:Undertake a comprehensive audit of the global
status of CCS covering projects, costs, policy andregulation and R&D; andProvide a realistic and contemporary view ofopportunities and challenges to CCS.

This work has:

Identified the ‘real’ status of CCS projects and key barriers to the global deploymentof CCS;
Provided a series of recommendations;Influenced the development of international and national policy; andEnabled the evaluation and tracking of the deployment of CCS annually.
資料616

15

GLOBAL CCS INSTITUTE

DELIVERABLES Four foundation reports:-

Status of CCS projects
Costs of CCS (power and other industrial
sectors)
Policy and regulation
Research and development One synthesis report:-

Overall challenges, barriers, gaps
Recommendations

 Two databases:-

CCS projects
Research networks

資料617

16

GLOBAL CCS INSTITUTEREPORT ONE: STATUS OF CCS PROJECTS

資料618

17

GLOBAL CCS INSTITUTETOTAL PROJECTS BY REGION
Globally:

only 7 large scale
operational CCS
projects in databaseno large scale, fully
integrated projects
greater than 1Mt CO2 in
the power generation
sector

資料619

18

GLOBAL CCS INSTITUTE

A COMPLETE APPROACH
The Global CCS Institute is ready to work in a co-operative mannerwith all stakeholders in the CCS arena. A holistic approach isneeded to address:


Early large scale demonstrationKnowledge sharing, including ‘learning by doing’

Development of legal and regulatory frameworks

Provision of short term financial incentives and longer term fiscal framework

Understanding and development of infrastructure requirements

Continued technology research and development

Community and public awareness and acceptance
資料620

19

GLOBAL CCS INSTITUTE

www.globalccsinstitute.com
資料621

20

(10)2009 セミナー最終纏め～ゼロエミッションを目指す
日本のクリーナーコール政
策～

資料622

Japanese Policy for Cleaner Coal
- Towards Zero Emission
Oct 13, 2009
H. KUNITOMO
Coal Division
Agency of Natural Resources and Energy
Ministry of Economy, Trade and Industry
資料623

1. The development of more efficient coal-fired
power plants
・・・・ Ｐ ２

2.

The commercialization of CCS・・・・ Ｐ 7

3. International cooperation in Clean Coal
Technology (CCT)・・・・ Ｐ10
資料624

1

1. The development of more efficient coal-fired power plants(1) Coal-fired power plants’ technological innovation and CO2 exhaust unit requirements
Coal-fired
Pulverized coal fired
Pulverized coal fired (the newest USC）

887g-CO2/kWh※1
800g-CO2/kWh※2(Isogo Thermal Power Station)

IGCC (1300℃-GT)
IGCC (1500℃-GT)
IGFC (target of EAGLE Project)758g-CO2/kWh※2709g-CO2/kWh※2593g-CO2/kWh※2

Oil-fired704g-CO2/kWh※1

LNG-firedGas-fired
Combined478g-CO2/kWh※1
408g-CO2/kWh※1（kWh：the sending-end）※１ CRIEPI News, No. 338※２ The trial calculation value and precondition of “A” power company: CO2 emission factor ofsteam coal 0.0247t-C/GJ (Source: The Calculation and Reporting Manual for Greenhouse
Gas)
Sending-end efficiency: the newest UGC41%,
資料625IGCC (1300℃GT）43%, IGCC (1500℃GT）46%,
IGFC55%2

1. The development of more efficient coal-fired power plants(2) Development of environment-friendly coal utilization technology in Japan Japan, which depends on imports for nearly 100% of its coal supply, hasbeen making a continuous effort to develop and implement high-efficiency
coal-fired power generation technology.
Development of High-efficiency Coal-fired Thermal Power Plants~ World’s Most Advanced Application of High-efficiency Plants ~資料626(Complied based on “Thermal and Nuclear Power” of October 2006)3

1. The development of more efficient coal-fired power plants(3) Environment-friendly coal utilization technology in Japan (power sector)Japan’s coal-fired power generation has achieved the world’s highest thermal efficiency(41.6%).
Installed capacity (by utilities) of coal-fired power plants in Japan is 37GW, which is 1/10 ofChina, 1/8 of the U.S., 1/2 of India and the equivalent of Germany.

Changes in the Coal-fired Thermal Power Plant
Efficiency by Country

Installed Capacity of Coal-fired Thermal Power
Plants by Country

Source: ECOFYS, “International Comparison of Fossil Power Generation
Efficiency” (2008)

2006 results:
41.6% in Japan, 40.0 % in Germany, 36.7% in the United 資料627
States, 35.9% in Australia, 32.1% in China, and 31.8% in India

Source: IEA, “World Energy Outlook 2008” and the website of theFederal Ministry of Economics and Technology, Germany4

1. The development of more efficient coal-fired power plants(4) Efficiency improvement of coal-fired thermal power plants

Source: “CoolEarth 50 – Energy Innovative Technology Plan”
資料628

5

1. The development of more efficient coal-fired power plants(5) Technology roadmaps toward 2050
Outline of technology roadmaps for Clean Coal & CCS
2000

2010

2020

2030

2040

40% reduction
compared with USC● IGFC
Demo
plant

2050

55%
(600 MW-class)

65% (A-IGFC)
30% reduction
compared with USC●IGCC
50% (1700℃ class)

41%
Demo plant

48%(1500℃ class)○USC●Advanced ultra-super-critical power generation (A-USC)

48% (750℃ class)
42% (600℃ class) 46%(700℃ class)

57% (A-IGCC)

about 10% reduction
compared with USC●Separation and capture of CO2
Capturecost$42 t-CO2

Pilot study$20s/t-CO2$10s/t-CO2●Geological storage of CO2
Large-scale 資料629●Ocean separation and capture of CO2
demonstration

6

2. The commercialization of CCS(1) Demonstration Projects (planned)
IGCC/IGFC (oxygen-blown)
Capture Ready

IGCC (air-blown)
Capture Retrofit/Pipeline/Storage

Storage

Coolgen Project: Scale up of EAGLE Project■ R&D：JPOWER/The Chugoku Electric Power Co., Inc.
■ Coal feed rate：1,100ｔ/d（170MW）■ Period：2010～2011（Feasibility Studies）

Osaki Coolgen Project

Nakoso Project■ R&D：11 power companies and CRIEPI■ Coal feed rate：1,700ｔ/d（250MW）■ Period：2009 (Feasibility Studies), 2010~2013（ Design andmachinery setting ）, 2014 ~Storage

Nakoso Power Plant■ R&D：RITE■ CO2 injection amount : About 10,400t-CO2■ CO2 injection rate : 20 to 40 t-CO2/day■ Period：2000～2007

Project Nagaoka■ R&D: JPOWER/MHI■ Quantity of processing gas ： 1,750Nm3/h■ CO2 capture ： 10 t-CO2/d■ Period ：2007～2009

JPOWER・
Matsushima Coal
Fired Plant(2) Pilot Scale Projects (CCS)
PCC
Post-Combustion(chemical absorption)
PCC
Oxy-fuel

Callide Oxy-fuel Project■ R&D：Japan （JPOWER, IHI, etc.)/Australia■ Scale：30MW■ CO2 capture ：30,000 t-CO2/year■ Period：2011～2014

Callide A Coal Plant

EAGLE Project
IGCC (oxygen-blown)
Pre-Combustion(physical absorption)■ R&D：JPOWER/NEDO■ CO2 capture : 20t-CO2/d■ Period：2008～2009
資料630 Chemical Absorption test
2010～2013 Physical Absorption test

Wakamatsu ResearchInstitute EAGLE test
facilities

72. The commercialization of CCS(3) Feasibility Studies bearing in mind the total system of CCS covering injectionof CO2.
In regard to CCS of CO2 occurring at a coal‐fired power station, developing a realistic trans‐
portation system is an important concern. During the present basic study, we will plan therealization and commercialization of the total system.

(4) Basic Research on CCT and CCS(1) Fundamental research related to coal gasification① Study on the efficiency improvement of power generation systems with CO2 capture
in integrated coal gasification combined cycle power generation② Study on Next-generation, High-efficiency Integrated Coal Gasification Electric Power
Generating Process (A-IGCC)(2) Basic Research on Membrane Technology資料631
for Separation of CO28

2. The commercialization of CCS(5) Establishment of Japan CCS Co., Ltd.

To implement the CCS Demonstration Project,
Japan CCS was incorporated in May 2008,
comprising the following 29 major Japanesecompanies:
 11 electric power companies (all majors)z Tokyo, Kansai, and Chubu, etc.
 5 petroleum companies (all majors)z Nippon, Idemitsu, Japan Energy, Cosmo, and Showa
Shell
 5 engineering companies (all majors)z Nippon Steel Eng., JFE Eng., Chiyoda, JGC, andToyo Eng.
 3 petroleum resource development (all majors)z Arabian Oil, INPEX, and JAPEX
 2 iron and steel companies
z JFE Steel and Sumitomo Metal Industries
 1 chemical, 1 general trading and 1 non-ferrous metal andcement companyz Mitsubishi Gas Chemical Companyz Mitsubishi Corporationz Mitsubishi Materials Corporation
資料632

9

3. International cooperation in Clean Coal Technology (CCT)(1) Promotion of CCS projects combined with Coal-fired Power Generation① Callide A (Oxy-fuel + CCS) Demonstration project by Japan and Australia (Queensland.
② Technical cooperation with China on CCS + EOR projects and environmental issues③ Japan – U.S. Collaboration on CCS (July 2009)④ Japan – Canada CCS Dialogue (Sep 2009)(2) Technical cooperation with Asian countries on CCT① Japan is promoting international cooperation through multilateral frameworks such as
APP and APEC, and bilateral frameworks.
② Major coal exporters to Japan such as Australia and Indonesia are especially important
for technical cooperation in CCT.
③ Cooperation Program with China and India on Renovation of Existing Coal-fired Power
Plants is expected to contribute to mitigating global warming.

資料633

Callide A Demonstration project launch event

At the Third Japan-China Energy Conservation Forum The third Meeting of the Japan-India Energy Dialogue10

3. International Cooperation in Clean Coal Technology (CCT)(3) Implementation of the “Clean Coal for the Earth” Initiative~ From Japan to the World: Dissemination of Clean Coal Utilization Technology
Diagram of Coal-fired Thermal Power Plant Efficiency in Japan andTechnology Transfer

資料634

11

3. International Cooperation in Clean Coal Technology (CCT)(3) Implementation of the “Clean Coal for the Earth” Initiative~ From Japan to the World: Dissemination of Clean Coal Utilization Technology

CO2 Emissions of Coal-fired Thermal Power Plants (2004)
Mt-CO22,500
2,000（▲387）（▲776）▲387 (mil. tons)+ ▲776 (mil. tons)+ ▲184 (mil. tons)▲1.3 bil. tons

1,500
1,000

2,269

1,949
1,562

500
0

1,493

（▲23）

269

246

ExsistingCutting-edge
Application
Case

Japan
Japan

（▲184）

572
ExsistingCutting-edge
Application
Case

US
US

ExsistingCutting-edge
Application
Case

China
China

Exsisting388
Cutting-edge
Application
Case

India
India

Note: In the case of applying the best practice (highest efficiency level of commercial power plants) of Japan to theexisting plants of each country.
資料635 Achievement data: World Energy Outlook 2006 (IEA)
Source: The Institute of Energy Economics, Japan (IEE Japan),

12Thank you for your kind attention!

資料636

(11) 閉会の辞

資料637

CLOSING REMARKSDr Frank M Mourits
Acting Chair
Expert Group on Clean Fossil Energy

Cleaner Coal: Moving towards Zero Emissions
APEC Clean Fossil Energy Technology and Policy Seminar
Incheon, Republic of Korea
13 October 2009
The theme of this week’s seminar was “Cleaner Coal: Moving towards
Zero Emissions.” Over the past two days, we have focused on some of the
key challenges that coal faces, not only in the APEC region, but also
everywhere else in the world where coal is produced and used. Speakers
from across the APEC region as well as India discussed their coal policies
and provided detailed updates on the coal supply and demand situation in
their economies. Other speakers focused on advanced clean coaltechnologies and on carbon capture and storage – a new technology thatmany believe will be needed to ensure the realisation of near-zero carbon
emissions. We have heard from both developed and developing APEC
economies, along with the IEA, on what path coal should take towards
achieving zero emissions.
From their own background and experiences, each of our speakers
discussed one or more salient issues that will affect the way coal will be
produced and used in the coming years. I think you will all agree that thecommon message we have heard is that fossil fuels will continue to be thebasis of economic growth for many APEC economies and the rest of theworld for at least several more decades.
However, it has also become abundantly evident that current fossil fueltechnologies cannot deliver the environmental performance necessary fortoday’s level of energy consumption, nor will they be able to do so whenhundreds of gigawatts of new power are brought online to meet future
electricity demand. The question many speakers tried addressing was:“Can fossil-fuel based systems and coal-based systems in particular be
developed and commercialized in the near or mid-term, so that they canprovide the large quantities of reliable, affordable and environmentally

資料638

sustainable power with near zero emissions that we will need throughout
the rest of this century? Speakers described a wide variety of research,development, and large-scale demonstration activities, which are being
undertaken by governments, the private sector, academia and R&D
organizations and which will ultimately have to answer that question.
As I mentioned, a growing consensus has been emerging over the past
few years that the only practical, effective and viable way to deal with theenvironmental emissions of coal is to implement carbon capture andstorage. We have heard this again yesterday afternoon in the technicalsessions. And it is this regard that I would like to quote from a letter that
the U.S. Secretary of Energy, Steven Chu, wrote yesterday to the Carbon
Sequestration Leadership Forum (CSLF), which holding a Ministerial
meeting in London yesterday and today. I summarise the following fromSecretary Chu’s letter:“Climate change caused by the carbon dioxide emissions from fossil fuels
poses clear threats to the well-being and economic prosperity of people inmany countries. Our prosperity depends on reliable, affordable access toenergy. Coal accounts for 25% of the world’s energy supply and 40% of
the carbon emissions, and is likely to be a major and growing source ofelectricity generation for the foreseeable future. For this reason, we must
make it our goal to advance carbon capture and storage (CCS) technology
to the point where widespread, affordable deployment can begin in 8 to 10
years.
Success is within reach, but will not come easily. It will require an
aggressive global effort, harnessing the scientific talent and resources ofgovernments as well as industry. To accelerate CCS technology on a
global scale both in the industrial and developing economies, we need tocontinue our cutting-edge research, enhance global collaboration toleverage our combined resources, share our knowledge and foster
capacity building around the world.
Without question, there are many other scientific breakthroughs that will beneeded to solve the energy and climate crisis, from energy storage tobuilding efficiency to reducing the cost of renewable energy. But finding
safe, affordable, broadly deployable methods to capture and store carbon
dioxide is clearly among the most important issues scientists have everbeen asked to solve. We can, and should, and must strive to do so within
the next 8 to 10 years.” End of quote.

資料639

Before ending, I would like to say a few words to inform you about the work
the APEC Expert Group on Clean Fossil Energy is doing. Most of you willprobably not be aware that with the financial support of APEC we arecarrying out anywhere from one to five projects a year, covering a wide
range of topics in the areas of clean coal technology and CCS. The final
reports resulting from these projects are all posted on our APEC website,
along with announcements on other new projects that we are planning.
Right now, we have six projects in progress, including what shapes up to
be a very successful CCS capacity-building workshop in Indonesia next
month. So, if you have any ideas for work your economy would beinterested in, please come and see me or contact any of my APEC
colleagues. We will be holding our annual EGCFE business meeting after
this seminar to review and discuss these projects.
In closing, I wish to once again acknowledge the organizations that havesupported this seminar. I want to thank our sponsors, which includes the
Ministry of Knowledge Economy (MKE), and our co-sponsors, the Korea
Institute of Energy Technology Evaluation and Planning (KETEP) and the
Korea Institute of Energy Research (KIER) for agreeing to host thisseminar. I also want to thank our other sponsors, Japan’s New Energy
and Industrial Technology Development Organization (NEDO), and theJapanese Committee for Pacific Coal Flow (JAPAC). And, finally, I want tothank the Incheon Global Fair & Festival Organizing Committee for the
fantastic dinner last night. We would not be here this week without all this
support.
I thank all of the speakers and chairs for their efforts and time to be with us
here. Lastly, I would be remiss not to acknowledge the tireless support ofthe many people who we all see, but rarely thank …those who work behindthe scenes at events like this, including the local organizing team, themanagement and staff of the hotel, and many others who’ve done such an
outstanding job. To them, I offer my special thanks.
At our business meeting we will begin planning the next Clean Fossil
Energy Technical and Policy Seminar, which Japan has graciously offered
to host. So, please watch our web site for more information on this event.
I thank each and every one of you for your active participation in thisseminar and hope that you have a safe trip home or wherever you areheaded. I look forward to seeing you at one of our future events.
Thank you.

資料640

2009 APEC Clean Fossil Energy
Technical and Policy Seminar
12-14 October 2009
Incheon, Republic of Korea

Closing Remarks
Dr. Frank Mourits
Acting Chair
Expert Group on Clean Fossil Energy
資料641

Ongoing Projects (2008-2009)1.

Planning and cost assessment guidelines for making new coal-fired
power generation plants in developing APEC economies CO2
capture ready (US)2.

Implementation of CO2 emission reduction technologies andmethods for fossil fuel installations (US)3.

Increasing the knowledge and awareness of carbon capture andstorage (Phase IV): CCS capacity building workshops in Indonesia
and China region (Canada)

4.

Assessment of the capture and storage potential of CO2 coproduced with natural gas in South-East Asia (Canada)

5.

Case studies of public education and information campaigns in
APEC economies, and development of best practice guidelines (US)6.

Actions by government and industry to promote LNG trade andinvestment in the APEC region (US)
資料642

New Project Proposals for
2010-2011
1. Fossil power plant efficiency and CO2 emissions monitoring
and reporting in developing Asian APEC economies
2. 2010 APEC policy initiative towards demand/supply outlook ofcoal and natural gas
3. CCS capacity building workshops in Southeast Asia (e.g.,
Thailand, Vietnam, Malaysia, Philipines)¾ EGCFE Website:
http://www.egcfe.ewg.apec.org
資料643

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