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Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
Emerging trends in oil & gas sectors in india (6 jan'04)
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Emerging trends in oil & gas sectors in india (6 jan'04)

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  • 1. PRESENTATION OUTLINEEmerging Trends INTRODUCTION – PETROLEUM SECTOR OVERVIEW REFINING & MARKETING in NATURAL GASOil & Gas Sector LNG INFRASTRUCTURE in India RECENT SPURT IN OIL & GAS DISCOVERIES SOME ARE WORLD CLASS GREATELY IMPROVED HYDROCARBON By PROSPECTIVITY OF INDIAN SEDIMENTARY BASINS SALIENT ACHIEVEMENTS OF NELPDr. Avinash Chandra NEW INITIATIVES BY DGH (PERSONAL VIEW-POINT) GAS HYDRATE PROSPECTS 1
  • 2. PETROLEUM SECTOR : AN OVERVIEW Oil and Gas plays key role in Energy Sector Share of Oil and Gas in Commercial Energy consumption India : 41% World : 63% Per capita consumption of petroleum productsINTRODUCTION India : 110 Kg World : 920 Kg Annual average growth rate for petroleum product demand 6-7%, whereas world average is 1.54% 8th Largest consumer of Oil & Gas, expected to be 4th largest consumer in next 10 years. 2
  • 3. Broad Investment Figures in the Oil & Gas Sector in India (25 Billion US$ / Year) TENTH PLAN (2002-03 to 2006-07) PSUs Rs. in Crores US $ in Billion Exploration & Production 59,469 or 12.93 Refining & Marketing 36,572 or 7.95 96,041 or 20.88 Pvt/JV Companies Likely on Exploration Possible on Production About 3,220 About 23,000 or or 0.70 (?) 5.00 (?) REFINING & MARKETING About 27.0 Billion US $We are broadly looking at Investment of around 6.0 Billion US $ per year Plus 0.4 Billion US$ on LNG (0.8 Billion US$ BY 2005)Country imported Crude Oil & Products worth 18.4 Billion US $ in 2003-04 3
  • 4. CRUDE IMPORTS Countries % MTPA Persian Gulf 65* 58.0 North Africa 3 4.5 West Africa 20 13.0CRUD IMPORTS % South America 6 5.3PERSIAN GULF 67 North America 0 2.6NORTH AFRICA 05WEST AFRICA 15 Far East 6 2.6SOUTH AMERICA 06 Russia 0 1.0NORTH AMERICA 03FAR EAST 03 TOTAL 100 87.0RUSSIA 01TOTAL 100 * Percentages fluctuates 4
  • 5. POSSIBLE GAS & OIL SUPPLY CRUDE OIL IMPORT SOURCES ROUTES Type of Crude Oil Country High Sulphur (60-63%) (Lube bearing 35%) Saudi Arabia 23.55 MMT in 2003-04 Delhi (Total import 90.43 MMT) (Non L Type 65%) - ube Iraq UAE Egypt84.4 30 Kuwait Dahej Oman 14 Low Sulphur (37-40%) Yemen 6 Nigeria Angola 6 Congo Libya 28 Malaysia Oil Supply Routes Brunei 2.6 MMt The crude oil baskett is well diversified and imports are made from Possible Gas Supply Routes different regions of the world 5
  • 6. INDIA IS SELF-SUFFICIENT IN THE REFINING & PRICE TRENDS : MARKET CRUDE OIL MARKETING SECTOR40 YEAR REFINING CAPACITY DEMAND FOR PRODUCTS INVESTMENT (MTPA) (MTPA) BY PSUs35 2003 0 - 4 116.97 105.2030 2006 0 - 7 137.07 120.40 ABOUT Rs. 14,000 Crs.25 (3.0 Billion US $)20 FUTURE CAPACITY BY PSUs15 EXPECTED 24.0 - ABOUT Rs. 28,560 Crs. BY 2012 (6.2 Billion US $)10 2004 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 (upto (Bina, Paradip Nov)Brent 20 19.32 16.97 15.82 17.02 20.67 19.09 12.72 17.97 28.5 24.44 25.19 28.83 38.01 & Bhatinda)Dubai 16.56 17.21 14.9 14.76 16.09 18.56 18.13 12.13 12.16 17.3 26.24 22.8 23.85 26.76 6
  • 7. Oil, Gas & Coal Fields Of India Rajasthan Upper Assam 126.9 BCM LEGEND 7.3 BCM Delhi Oil Fields Cambay Gas Fields 96.9 BCM Coal Fields Kolkata AAFBNATURAL GAS Mumbai K. G. 51.9 BCM 25.2 BCM Mumbai Off. 393.34 BCM Chennai Cauvery Balance Rec. : 735 BCM 23.4 BCM Reserves R/P Ratio : 26 Yrs 7
  • 8. GAIL (INDIA) LIMITED PROPOSED NATIONAL GAS GRID Gas Import Options BHATINDA Turkmenistan NE DELHI BAREILLY P AL ITANAGAR GANGTOK BHUTAN AURAIYA Delhi JAGDISHPUR MATHANIA DISPUR KOHIMA Iran KOTA PHOOLPUR SHILLONG GAYA IMPHAL BANGLADESH VIJAIPUR BOKARO AGARTALA AIZAWL DAHEJJAMNAGAR MYANMAR Qatar, Oman Dahej KOLKATA HAZIRA BHUBANESHWAR Myanmar MUMBAI PUNE A 1 BLOCK, VIZAG MYANMAR Malaysia, Indonesia DABHOL KOLHAPUR KAKINADA Australia HYDERABAD Yemen GADAG RAICHUR NELLORE CHITRADURGA HASAN BANGLORE Cochin MANGLORE CHENNAI LENGTH - 7890 KMS. LNG imports would supplement KANJIRKKOD TIRUCHCHIRAPALLI COST - 20,200 CRORES Gas P/L Import gas pipeline imports and help in COIMBTORE KOCHI development of pipeline grid TUTICORIN ( 4.4 B. US $ ) LNG Import 8
  • 9. LNG 9
  • 10. INDIA – LNG PROJECTS LNG CARRIERS REQUIRED FOR INDIAN LNG PROJECTS Average Delivery No. of Vessels LNG Sites Capacity Capacity Required Remarks MTPA ship (Pa) Ton (135000M3) Dahej, Gujarat 5 1.700,000 3 Established Hazir, Gujarat 2.5 1.700,000 1.5 Established Dabhol, Maharashtra 5 1.700,000 3 Established Cochin, Kerala 2.5 1.700,000 1.5 Planned Ennore, Tamil Nadu 5 1.700,000 3 Planned Hazira 2.5 1.700,000 1.5 Planned Pipavav, Gujarat 5 1.700,000 3 Under Study Jamnagar, Gujarat 5 1.700,000 3 Under Study Kakinada, Andhra Pradesh 2 1.700,000 1 Under Study Mumbai, Maharashtra 2.5 1.700,000 1.5 Under Study Gopalpur, Orissa 2.5 1.700,000 1.5 Under Study Total 33.5 24 10
  • 11. INDIAN LNG DELIVERY CAPACITY PER SHIP ( 135,000 M3) Distance to No. of Days per DeliveryReceiving Terminal / Volume per Assaluyeh Voyage per round trip capacity perOperating Companies Voyage (ton) Nautical Mile year (Days) ship p.a (ton)Reliance / Jamunagar Guillarat, 650 Km 1,040 60,613 44.79 7.81 2,714,643 Northwest Bombay Indigas / Trombay Maharashtra, 40Km 1,260 60,544 39.62 8.83 2,398,900 from Bombay Petronet / Cochin (Kerala, 1,100 Km 1,750 60,390 31.53 11.10 1,903,873 South of Bombay)Ennore (Tamil Nadu, 26 2,590 60,127 23.35 14.99 1,403,822 Km from Madras) Vavasi Gopalpur 2,960 60,011 20.95 16.70 1,257,429 11
  • 12. Cost Comparision Gas Pipeline / LNG vessels From Assalueh to India (Dr. Chandra’s view – point, there are tentative estimates) LNG IMPORT PROPOSALS: 5-10 Years CAPACITY Terminals COMPANIES LOCATION LNG Vessels Gas Pipeline (MMTPA) PETRONET 5.0+2.5 2 Dahej (697 mil.US$) 12 LNG vessels : 2,160 M.USD Main gas trunk pipeline : 3,500 M.USD LNG (10 by 2006) Kochi (418 mil.US$) (including compressor stations) Export Terminals : 2,500 M.USD Domestic pipeline network : 500 M.USD Indian/ 2.5 1 Many offers Kakinada (additional cost) Private-JV 2.5-5 2 Reliance Jamnagar, Industries Hazira Receiving Terminals : 2,000 M.USD Pipeline operation cost : 1,575 M.USD 3.0 1 GAIL/ TEC/ Trombay Operation LNG vessels : 2,592 M.USD Compressors operation cost : 1,589 M.USD (future 6.0) TOTALFINA Operation Terminals : 2,000 M.USD 2.5 1 TIDCO/UNOCAL/ Ennore CMS/ Birla Group/ Port charges : 1,488 M.USD Transit fee : 6,570 M.USD Woodside TOTAL COST : 12,740 TOTAL COST 13,734 Foreign 10.5 3 British Gas Pipavav Companies Shell Hazira Enron Dabhol * My personal tentative estimates Likely investment 4-5 billion US$ 12
  • 13. MAP SHOWING EEZ & 350 NAUTICAL MILE LIMITSEDIMENTARY BASINS OF INDIA EEZ INDIA LIMITBASINAL AREA : 3.14 M.SQ.KMSEDIMENTARY AREA IS ABOUT ANDAMAN & NICOBAR4.07% OF THE WORLD’S TOTAL EEZ LIMIT A ISLANDS K ANSEDIMENTARY AREA. SRI LCOULD WE THEN NOTPRODUCE ATLEAST 2-3% OF EEZWORLD’S TOTAL OIL & GASINSTEAD OF MERELY 0.9% AS MARITIMEAT PRESENT ? 350 NAUTICAL MILE LIMIT BOUNDARY 13
  • 14. OIL & GAS RESERVES ESTIMATES (AS ON 1.4.01) Oil Gas MMT MMTOE Total Geological (Initial in-Place) 5,124 1,893 7,017OUTER LIMITS Initial Recoverable 1,447 1,100 2,547 OF INDIAN Balance Recoverable 714 735 1,449CONTINENTAL Reserve/Production Ratio (in SHELF Years) 22 26 - Total Prognosticated Reserves : 28 billion MT (Oil + OEG) Author’s Estimate of Prog. Reserves : 32 billion MT (Oil + OEG) MMTOE : Million Metric Tonnes of Oil Equivalent 14
  • 15. Natural Gas Demand / Supply RESOURCE BASE ProjectionsA. DGH Revised Estimates : 32 billion tonnes (235 B.bbl) 391B. Earlier Hydrocarbon Resource : 28 billion tonnes (205 B.bbl) 50% could be converted to inplace proven reserves i.e. 14 billion tonnes 400 Supply CBM * 313 350 Resources already established : 7.2 billion tonnes (52 B.bbl) 300 Demand 300 MMSCMD--- Additional to be established : 6.8 billion tonnes (49 Bbbl) LNG 231 250C. The upgradation can be made in the next 15 – 20 years 200 205 151 170 150 155D. Additional production from Additional rec. reserves 3.06 billion tonnes 150 142 6.8 billion tonnes (O+OEG) Prodn. Rate Oil 24 MMt 45 45 45 100 2 10 15 Around 50 % oil & 50% gas Gas 43 BCM Oil rec. 30% & gas rec. 60% 50 70 95 95 95E. Balance recoverable reserves : 1.4 billion tonnes (10 B.bbl) 0 2001-02 2006-07 2011-12 2024-25 Current Production - Oil : 32 MMt / year (234 M.bbl) Gas : 29 BCM / year SUPPLY PROJECTIONS BASED ON PRESENT RESERVES Thus, Total prodn. Could be (D+E) : Oil 56 MMt/year Gas 72 BCM/year * ALMOST 100% INCREASE DUE TO RECENT DISCOVERIES IN PVT./J.V. SECTOR (i.e. a peak prodn. of 197 MMSCMD) 15% higher if DGH estimates are used INSTANT DEMAND FOR NATURAL GAS AVAILABLE IN THE COUNTRY This can enable Oil & Gas production to increase more than 2 folds * 15
  • 16. Natural Gas Production Trend in India Natural Gas Production Trend in India (Including CBM ) Additional impact of new gas ’10’ (C.C.) 60.2 (C.C.) 79.9 + CBM additional ’10’. Total Possible (impact of 80 (C.C.) 54.7 20MCMD More CBM by 2021-25 70 (C.C.) 195 (C.C.) 40.8 250 60 (C.C.) 240 Impact of other new gas ’10’ + CBM ’10’. Total 20 MCMD More Accounted (219) 50 200 Gas Prod. In MMSCMDBCM 40 (C.C.) 150+10+10= 170 (34.4) Not Accounted (165) (165) 30 (34.4) 150 (29.8) (150) (26.6) Production from East Coast 20 (112) blocks in N.EC, Cairn, 100 shallow water GSPCL, Off. 10 (94.2) (94.4) Mahanadi not taken in to (73) account. 0 50 1970-71 1975-76 1980-81 1985-86 1990-91 1994-95 1997-98 1999-00 2002-03 2006-07 2011-12 2016-17 2021-22 0 2006-07 2011-12 2016-17 2021-22 YEAR Minimum impact of CBM taken into account. Potential Exists but production yet to start 16
  • 17. PATTERN OF GAS USE (1999-2000) EXPECTED PATTERN OF GAS USE (2011-12) TOTAL 65 MMSCMD TOTAL 135 MMSCMD PLUS SPONGE IRON OTHERS 2.5% CITY GAS &SPONGE IRON 3.5% CNG 12-14% SHRINKAGE & OTHERS 12% SHRINKAGE & IC 4% 6% IC 4% 4.0 18 5 3.0 7.0 5 FERTILISER 30 + 2% 26 39 6 25 62 FERTILISER 40% POWER 38% POWER 46 + 50% 17
  • 18. Domestic Crude Oil Production / PETTERNOF GAS USE Product Demand Widening Demand - Supply GapTotal Amount 65 MMSCMD 135 MMSCMD 1999-2000 2011-12 400 368 Production (%) (%) 350 DemandPower 38 47+ 2% 300 Equity oil abroad 250 195Fertiliser 40 30+ 2 200 MMTShrinkage & I.C. 4 4 150 96 110Sponge Iron 6 3.5 120 100 56 32 33Others 12 2.5 50 45 65City Gas & CNG 0 13 0 2001-2002 2002-03 2011-12 2024-25 100 100 17 REFINERIES WITH 117 MTPA CAPACITY (TOTAL SELF-SUFFICIENCY) REFINERIES IN ALL PRODUCING AREAS OR WITHIN 300 KMS IN NON-PRODUCING AREAS. INSTANT DEMAND FOR CRUDE OIL AVAILABLE IN THE COUNTRY * 18
  • 19. MEHSANA CHANGING EXPLORATION SCENARIO N.BALOL BALOL BECHRAJI W.BECHRAJI JOTANASOBHASAN LINCH AKAJ MANSA CAMBAY BASIN N. KADI PALIYAD LIMBODRA S. KADI Total Sedimentary Area : 3.14 M. Sq. Km. KALOL GANDHINAGAR Mod. to Mod. to Well Expl. 1995 - 96 Well Expl. 1998 - 99 SANAND AHMEDABAD AHMEDABAD 0.498 0.498 NANDEJ HIRAPUR 15% WASANA 15% NAWAGAAMPoorly Poorly 41% DHOLKA Expl. 17% 17% ASMALI VATRAK 50% Expl.0.529 0.529 KANWARA 18% 27% Unexplored AKHALJUNI CAMBAY SISWA ANKLAV 1.276 N.KATHANA KATHANA BARODA Current Annual 3.23 BCM Expl. Unexplored Expl. PADRA Gas Prodn. DABKA Initiated 1.557 Initiated JAMBUSAR N.SARBHAN 0.556 0.837 Pre-NELP S.MALPUR MATAR NADA JAMBUSAR Envisaged Annual 5.22 BCM Mod. to 2002 - 03 GANDHAR PALEJ Gas Prodn. at end Well Expl. 0.535 Unexplored PAKHAJAN DAHEJ X Plan (2006 0 - 7) 17% 1.019 BHAVNAGAR GULF ANDADA ANKLESHWAR 32% OF MOTWAN SISODRA KUNDARA CAMBAY Poorly Expl. 19% KIM KOSAMBA 0.590 OLPAD BHANDUT PARVATI 32% LAKSHMI SURAT AMBE HAZIRA Expl. Initiated NELP – I, II & III 0.996 NORTH TAPTI GAURI 19
  • 20. MUMBAI OFFSHORE AKM FIELD NAMES ADIYAKKAMANGALAM CAUVERY BASIN ATK BVG KI ATTIKKADAI BHUVANAGIRI KALI KARAIKAL BASIN KMP KAMALAPURAM NAGAPATTINAM MID KKL KARAIKALTAPTI SOUTH TAPTI TANJORE KZ KIZHVALUR KLP KOVILKALAPPAL Current Annual 21.59 BCM KA KNR KUTRALAM KUTTANALLUR Gas Prodn. MTR NLM MATTUR NANNILAM VEDARANNIYAM NRM NARIMANAM NY NEYVELI Envisaged Annual 20.43 BCM PVM PALLIVARAMANGALAM Current Annual 0.40 BCM PP PERIAPATTINAM Gas Prodn. at end PE PERUNGULAM Gas Prodn. X Plan (2006-07) PU RV PUNDI RAMANAVALASAI TKR THIRUKKALAR TVR TA THIRUVARUR TULSAPATNAM Envisaged Annual 1.23 BCM VDR VADATHERU Gas Prodn. at end RAMANATHAPURAM RAMESWARAM X Plan (2006 0 - 7) LEGEND GAS FIELDS OIL SRI LANKA GAS FIELDS TO BE PUT ON GAS TUTICORIN PRODUCTION IN NEXT FIVE YEAR PLAN 20
  • 21. KAKINADA N GODAVARI RIVER P RAVVA KRISHNA M Assam & North GODAVARIKRISHNA BASIN Eastern States R RIVER (Excluding Deep Water) Current Annual 1.96 BCM Gas Prodn. Q Oil Discovery 2001 Envisaged Annual 2.824 BCM TRIPURA Gas Prodn. at end Gas Discovery 2001 X Plan (2006 0 - 7) ROKHIA KG-DWN-98/2 Current Annual 2.45 BCM Gas Prodn. Envisaged Annual 2.78 BCM Gas Prodn. at end (Excluding Deep Water) X Plan (2006-07) 21
  • 22. Rajasthan Basin PUGAL Tanot RECENT SPURT DandewalaBaggi Tibba TANOT SadewalaKharatar Manhera Tibba OIL Baghewala IN ONGC RAMGARH Current Annual 0.1 BCM Ghotaru Bakhri Tibba JAISALMER Gas Prodn. Envisaged Annual 0.23 BCM OIL & GAS DISCOVERIES Gas Prodn. at end X Plan (2006-07) (Excluding New finds) Heavy oil field Gas fields 22
  • 23. RESERVES ACCRETION TREND NELP SCENARIO 400 Average Line 115 MMT for the period 1992-2000 / year 348 ACCRETION IN MMT (O+OEG) 329.61 350 INPLACE RESERVES 300 226.6Geophysical and 250 Geochemical 200 166.11Surveys carried Average Average 150 out by DGH 1992-2000 1992-2000 115 100 50 0 2000-01 2001-02 2002-03 2003-04 Year 23
  • 24. OIL & GAS DISCOVERY TREND NELP SCENARIO NEW SIGNIFICANT DISCOVERIES KAREWA AREA Million Sq. Km. DISCOVERIES UP TO 200m ISOBATH 1.784 20 DISCOVERIES HIMALAYAN FORELAND SPITI -ZANSKAR INCLUDING DEEP WATER 3.14 DAMODAR ASSAM SHELF 16 RAJASTHAN GANGA ASSAM-ARAKAN DISCOVERIES - 57 CAMBAY SAURASHTRA KUTCH VINDHYAN SOUTH REWA SATPURA BEN- FOLD BELT LEGENDNO. OF DISCOVERIES GAL BAY NARMADACHATTIS - PRE-NELP 13 CATEGORY - I BASIN OF LAKSHMI BOMBAY GARH BASTAR BENGAL CATEGORY - II BASIN OFF. DECCAN SYNECLISE CATEGORY - III BASIN KORI- MAHANADI CHINNEWALA COMORIN DEEP BHIMA - KRISHNA PRANHITA - GODAVARI CATEGORY - IV BASIN DEEP SEA BASIN TIBBA PRE -CAMBRIAN BASEMENT / OFF. KALADGI GODAVARI NELP 19 TECTONISED SEDIMENTS ANNAPURNA CUDDAPAH 0 85 E DEEP OFFSHORE ANDAMAN BAGHJAN, 15 KERALA KONKAN - - - NARCODAM NICOBAR DEEP OFFSHORE CAUVERY MATIMEKHANA, SARASWATI VASAI EAST NOC’s 25 CHABUA & RAAGESHWARI N. CHANDMARI GR-F Delhi 10 KAMESHWARI Rajasthan 9 MANGALA Basin BANAMALI & LAIPLING GAON 10 N-A, N-C & N-V-1 RJ-ON-90/1 SONAMURA CB-ONN-2000/1 DHIRUBHAI – PK-2 I N D I A Kolkata 9, 10, 11 & 15 CB-ONN-2000/2 BHEEMA, NS CB-OS/2 ENDUMURU-9 Mumbai 5 NMT-2 BAY G4-2-AB OF KG-DWN-98/3 BAY BENGAL DHIRUBHAI – VASAI EAST & WEST OF BENGAL 1, 2, 3, 4, 5, 6, 7, 8, 16 D-6 LAKSHMI D-5 KANAKDURGA A Chennai KG-DWN-98/2 N 0 AMBE D ANNAPURNA A 2000-01 2001-02 2002-03 M GAURI PADMAVATI A N PARVATI Oil 0 200 400 & Year GS-49 & GS-KW CBX-1 Gas Km 24
  • 25. BLOCK KG-DWN-98/2 (D5) Deep Waters - K.G Basin SIGNIFICANT DISCOVERIES LEADS AND PROSPECTS KAKINADA K.G. BASIN EXPLORATION GODAVARI RIVER P ACTIVITIES KANAKA DURGA RAVVA RAVVA CARRIED OUT PADMAVATI2D (LKM) : 6457 M3D (Sq.Km) : 2260 KRISHNA R RIVERDrilled wells : 6 0M 50Discoveries : 3 ANNAPURNA 1000 M Proved Gas Field Proved Oil Field Prospects/Leads Oil Field Gas Field 0M 0 Discovery Courtesy: CEIL 15 Courtesy: CEIL 25
  • 26. NEW DEEP WATER DISCOVERIES Deep Waters - K.G Basin BLOCK KG-DWN-98/3 (Reliance) KRISHNA – GODAVARI BASIN NELP- I BLOCK KG-DWN-98/3 (D-6) WELL A1 (Dhirubhai – 1) INDEXGas Discoveries Late Miocene Sands (1850- 2200m)Identified Locations Dhiru-1 FLAT SPOT Gross Pay : 250m (7 Sands Net Pay : 140m Dhiru-3 Dhiru-2 Ø : 22% More discoveries expected in this area. K : 100–5000 md Sw : 34% IGIP : 3.35 TCF This block can produce 30 to 40 MMSCMD of Test Production : 40 MMSCFD Natural Gas. In this block Well Depth : 2903m biggest discovery in the world for natural gas for the year 2002 was found SEISMIC SECTION THROUGH DISCOVERY WELL 26
  • 27. Deep Waters - K.G Basin BLOCK KG-DWN-98/3 (D-6) D-9 NEC-OSN-97/2 0.5 D15 NEW DISCOVERIES: D9 DHIRUBHAI 9, 10 & 11 D11 D10 TWT IN SECS. 1.5 2.5Depositional SystemInterpretation &Discrete AmplitudeGeobodies (enlarged) SEISMIC SECTION THROUGH DISCOVERY WELL DHIRUBHAI-9 DEPOSITIONAL SYSTEM INTERPRETATION Courtesy:RIL 27
  • 28. Gulf of Cambay SIGNIFICANT DISCOVERIES New Discovery : VASAI WEST (B-22)Lakshmi Field Gas ProductionCurrent Rate : 3.0 MMSCMD GULFPeak Rate : 3.4 MMSCMD OF CAMBAY DST Test RatesLakshmi Gas 0.408 MMSCMD Oil 15.68 tonesGauri Gas 0.532 MMSCMD Oil 141.75 tones CB/OS 2 -Ambe Gas 0.001 MMSCMD Oil 87.72 tones PARVATIParvati Oil 242.15 tones N. TAPTI HAZIRA LAKSHMI AMBE GAURI Courtesy: CEIL 28
  • 29. OPERATOR : CAIRN ENERGY NEW DISCOVERIES : RAJASTHAN BASIN DE LH PAK IST AN N-C I– N-V-1BLOCK : RJ/0N-90-1 SA MANGALA IN RG AS N-A OD -B HA B SU RID Known Gas NEW DISCOVERIES : R GE AU Producing Area AG ARCH RAJASTHAN BASIN -N BIK ANER R R NE GAR H PU AM KA HAN F GE B IK J- K IS L SHE BI NAG AUR POK H ARAVALLI RAN KAMESHWARI M H SARASWATI NACHNA HIG ARA IG H SHAHG ARH + N + RAAGESHWARI JAISALM ER + LO W + + + POKRAN ER + M IN + JO DHPUR AL S + IS -B A+ GUDA JA UB + + S + + BARM ER + + + GR-F + + BARM + + + + + + + + New Oil & + + + ER G Gas Province + SAN CHO R Prospects RAB 0 50 100 km + Oil Discovery + IG NEOUS RO CKS EN SCALE 29
  • 30. STATUS OF PEL AND ML AREAS AS ON 1-6-1996SALIENT ACHIEVEMENTS OF NELP PEL 203 ML 163 TOTAL 366 30
  • 31. Status of Exploration Rounds 80 72 70STATUS OF PEL 60AND ML AREAS 50 45 46 45 48 40 AS ON 1-4-2003 34 28 27 25 25 2323 27 2323 24 30 2120 20 18 13 12 10 10 10 6 5 7 7 7 5 5PEL 273 0 IV V VI VII VIII JV NELP-1 NELP-2 NELP-3 NELP-4ML 245 (1991) (1993) (1993) (1994) (1994) (1995) (1999) (2000) (2002) (2003)TOTAL 518 No. of Blocks Offered No. of Blocks Bid For Blocks Awarded - 4 5times more blocks are awarded under NELP each year, compared to earlier rounds due to better terms and excellent prospectivity of new blocks. 31
  • 32. AWARDED ACREAGE DISTRIBUTION PVT. SHALLOW NOC (Pre-NELP) OFFSHORE 0.23 0.18 ONLAND 0.10 0.10 16% 7% 24% 13% NEW INITIATIVES 77% 63% BY NELP- I, II III & IV 0.76 DEEP WATER 0.48 DGHTotal PEL Area – about 1.3 M. Sq. km. Total NELP Area- 0.99 M. Sq. km. 32
  • 33. GIANT DISCOVERIES OF THE WORLD BY DECADE CUMULATIVE TURBIDITE GIANT VERSUS GIANT TURBIDITE DISCOVERIES BY DECADE RESERVES VERSUS TIMENumber of Discoveries 15 Turbidite Giants 50 Cumulative Ult. Recoverable (BBOE) 10 Cumulative Gas 5 40 Cumulative Oil/Cond. 0 Gas 30 120 Cam- pos All Giants 20 West 80 California Africa OIL & Cond. 10 Gulf of Oil & Mexico 40 Natural Gas Cond. North Sea 0 1890 1900 1910 1920 1930 1940 1950 1960 1970 1980 1990 0 1881- 1891- 1901- 1911- 1921- 1931- 1941- 1951- 1961- 1971- 1981- 1991- YEAR 1890 1900 1910 1920 1930 1940 1950 1960 1970 1980 1990 1998 Source : Oil & Gas journal Source : Oil & Gas journal 33
  • 34. NEW INITIATIVES SATELLITE GRAVITY MAP MAHANADI EASTERN OFFSHORE -NECDEEP WATERS KG 1 1 EXTENSION OF SHELFAL HORST & GRABEN COMPLEX P A 2 2 COROMANDAL DEPRESSION L EAST COAST C A A R 3 3 850 EAST RIDGE U V E R Y 34
  • 35. DEEP WATERS - EAST COAST WORLD’S BIGGEST GAS DISCOVERY 80 NEW PLAYS MAPPEDHYDROCARBON (2002) 1PROSPECT MAP 3 4 2DEEP WATERS On acquisition of 3D seismic data, more discoveries expected in this area. KG-DWN-98/3 EAST COAST EOCENE CARBONATE BUILD-UPS/SLUMPS 6 OPERATOR : RELIANCE INDUSTRIES LTD. GODAVARI RIVER P KANAKA DURGA RAVVA SLUMP / TURBIDITE / PADMAVATI EOCENE-MIOCENE CHANNEL ZONE M EOCENE R KG-DWN-98/2 CARBONATES / ANNAPURNA TURBIDITES ZONE OPERATOR : CAIRN 5 ENERGY 35
  • 36. DEEP WATER PLAY TYPES DEEP WATERS - EAST COAST CAUVERY-PALAR BASIN - EAST COAST MIO-PLIOCENE TURBIDITES & DISTAL MARINE FANS GIGANTIC GRAVITY SLIDES / STRUCTURES SW 2000 2500 EC 95-210 3500 4000 4500 NE P SW 2200 EC 95 2 - 20 2600 2800 NE A LK.G. BASIN 4 A RAVVA R Bright Events TWT Mio. Top 0M 50 1000 M 5 5 TWT IN SEC. M 00 15 Oligo. To p 6 Cret Mio. Top Eoc. Top Depositional System 6 . Interpretation & Discrete Amplitude Top Geobodies (enlarged) Pa Oligo. To leo p .T op Eoc. To p Colossal sized gravity slumps - 20,000 Sq.km (20 km wide, 1 km amplitude, 100 km long). Three Major Transgressive Sand Bodies. Gigantic in size - 18,000 Sq.Km (180km x 100km) Similar structures are HC bearing in North Sea (Gryphon, Leadon & Balder fields) 36
  • 37. MAHANADI-NEC OFFSHORE MAHANADI-NEC OFFSHORE GEOLOGICAL SECTION HYDROCARBON POTENTIAL A B BURIAL, THERMAL & SOURCE ROCK MATURITY MAHANADI ONSHORE MAHANADI OFFSHORE MATURATION HISTORY AT CRETACEOUS LEVEL MON-2 MON-3 MND-4 MND-6 Time (Ma) 65 54 38 26 7 0 0 CRET. PAL. EOC. OLIG. MIO. PL.-R NEC-1 0 0 1 40 MND-5( KM ) 800 Ro = 0.50% 2 D-10 % Ro = 0.70 1200DEPTH Depth (Km) 5 160 0 Ro = 1.00% N 4 1.30% D-7 D-8 D-9 Ro = Cuttack D-6 MON-2 6 Basement Pliocene - Recent 25 Bhubaneshwar Miocene 0 0 10 200 200 Paleocene - Eocene 8 MON-3 ILK A E. Cret. (Volc. + Sed.) + Late Cret. (Sed) CH KE 0 50 Km. LA MND-4 MND-6 Scale E. Cret (Volc.) Immature (R0<0.50%) Main generation (0.70%<R0<1.30%) 860 870 Precambrian (Granite + Gneiss) Early maturation (0.50%<R0<0.70%) Wet and dry gas generation (R0>1.30%) 37
  • 38. NEW INITIATIVES SOUTHERN TIP OF INDIA TECTONIC SHELFAL HORST-GRABEN COMPLEX FRAMEWORK CAPE COMORIN DEPRESSION MANDAPAM DELFT HORST CAPE COMORIN HIGH KORI COMORIN DEPRESSIONDEEP WATERS KANYAKUMARI RIDGE KORI COMORIN RIDGE LAXMI LACCADIVE DEPRESSIONSOUTHERN TIP LAXMI LACCADIVE RIDGE MANNAR DEPRESSION NORMAL FAULT STRIKE-SLIP FAULT 38
  • 39. SOUTHERN TIP OF INDIA PLAY TYPES NEW INITIATIVESTIME STRUCTURE MAP NEAR TOP OF EARLY OLIGOCENE INDIA ST -O1 89 K-3 -01 A B STRUCTURAL D1 -19 -O 1-1 4 -O 1-1 2A PROSPECTS -O1 ST ST ST DEEP WATERS ST -O 1- 06 7 1-1 D3 ST ST-O D2 -O D4 1- 08 LEGEND -16 -O1 ST ANTICLINAL TRAP WEST COAST RE -06 TECTONIC TRAP A 2 1-1 ST-O NORMAL FAULT 1 1-1 REVERSE FAULT ST 0 100 km ST-O -O1 -02 SCALE STRIKE-SLIP FAULT LARGE STRUCTURAL TRAPS - A : 1000 Sq.Km B : 3600 Sq.Km 39
  • 40. WEST COAST BASIN WEST COAST BASIN SATELLITE GRAVITY & SEISMIC COVERAGE MAPS TECTONIC FRAMEWORK Sh en rab Deccan se elf Saurashtra LAXMI Horst- G urat ion S s Peninsula res Sh Surat Dep SH W el MuHigh oug DECCAN TRAPS C- Ri fM EL 2K D1 Mu 2-2 mb FA arg 3A Mumbai L KO KO I B mb W 00 2-2 ai R C-2 Deccan in T 30C-2K 0 Shelfairi High D1 R K2 Mumbai RI W 2-2 -2 -2K -19 ai atn Plateau r2 5A La WC -2K2 WC 2-1 8 MUMBAI a Sh x HO -2K 7 1 CO g 2-1 m h LA WC -2K l Hors 7 Rid xmi WC RS iR 2-2 C O IN elf M XM -2K INDIA Ratnagiri ge 6 OR WC K2-1 T id M -15 La DEPRESSION I– C-2 LA K2 OR DG ge W C-2 -14 Ratnagiri LA Cannanor W K2 RATNAGIRI XM IN -2 t WC GR DEP RI CC 3 4 -2K 2-1 Ke0200 1000 AD I AB WC Goa 1 Shelfal Horst and – 50 Gr E DE IV EN ESSION ral LA 2 Indian E 2-1 ab Graben Complex 40 0 0 WC -2K a -K CC R e en 1 Laccadive PR 2-1 -2K AD CO WC Arabian 2000 on 0 2-1 Craton ES Rift Com -2K 2 Shelf Margin WC MP IV Arabian SIO ka 9 E R K2-0 8 LE W C-2 2-0 -2K n plex N WC Abyssal X 2-07 System WC-2K 3 Alleppey platform Arabian 2-06 She Abyssal 400 WC-2K D2 IDGE D2 0 2-05 Cochin WC-2K lf 5 2 Abyssal WC-2K 2-04 Plain Ridge 4 D3 D3 4 300 Laxmi Laccadive Plain WC-2K 2-03 Cochin Plain 0 2-02 WC-2K p Depression COCHIN D4 Dep adwee D4 ion 2-01 WC-2K 4000 WC WC 3 WC ress Lakshadweep -2K -2K Depression 5 Laxmi Laccadive -2K2- sh 2-26 2-22 AR 2000 NN SIN 21 Lak 0 300 Km. Alle au Plate 4000 Ridge 40 0 200 Km. MA BA 00 B SU ppe AFTER BISWAS et.al (1988) y 40
  • 41. KERALA-KONKAN OFFSHORE GEOLOGICAL SECTION NEW INITIATIVES LINE WC-2K2-06 Shelfal Horst Arabian Abyssal Lacc adive Ridge Graben Complex Plain Lowered flank High standing part Lakshadweep Depression Kasargod-1 WSW NE Cannanore ENE Recent 1 Rift System L. Mio. Oligo-E. Mio Depth (Km) Water bottom 2 Eocene 3 4 Water bottom ANDAMAN 5 Seaward Dipping Reflectors OFFSHORE SEDIMENTARY COVERBASEMENT COMPLEX RIFTED CONTINENTAL CRUST UPP. MIO TO RECENT VOLCANIC PRE - SANTONIAN CRUST WITH THIN CONTINENTAL CRUST EOC TO MID. MIO VOLCANIC PRE - SANTONIAN CRUST WITH K 2-06 THIN CONTINENTAL CRUST MODIFIED BY UPP. CRET. TO PALEOCENE WC-2 HOTSPOT VOLCANISM IN EARLY TERTIARY CENOZOIC OCEANIC CRUST UPP. CRET. 41
  • 42. ANDAMAN-NICOBAR ANDAMAN-NICOBAR GEOLOGICAL SETUP TECTONIC ELEMENTS Irrawadi Basin BAY Sagaing Fau Gulf of OFCONCEPTUAL MODEL IN Martaban BENGAL Andaman BAS SIN E RRAC Microplate BA EP lt RC DE k KA IONARY PRISM MERGUI TE lcoc RE BAC VOLCANIC ARC FO FORE ARC M t. A Indian Plate Sunda NINETY DEGREES RIDGE ACCRET Plate Ninety Degrees East Ridge H NC ANDAMAN RY NTA TRE SEA VOLCANICS IME H IG SED H Su SPREADING E R m TU at CENTRE C ra U TR F S au 0 200 Km. SUMATRA R TE l t U O 42
  • 43. ANDAMAN-NICOBAR ANDAMAN-NICOBAR ADJOINING AREA LEAD ST4 AN-99-07 AN-99-08 ST6 ~~~ ~ ~~~ ~~ GAS HYDRATE AMPLITUDE MAP ST6 Water Bottom Free gas Reflection ST4 ~~ ~~~~~ ~~ST1 7 Gas Hydrate Prospects Mapped ST1 ST4 SeST2 ST5 al All Prospects have high ST2 ~~ ~~~~ ~~ ~ ST5 Gas Water Reflection amplitudes BSRST7 Prospective Area 3000 Sq. Km. ~~~ ~ ~~~ ~~ ST3 ST3 ~~ ~~~~ ~~ ~ Linear trend of high amplitudes BSR Free Gas Flattened along western edge of Fore Arc Resources at Basin ~~ ~~~~ ~~ ~ 23 BCM Sea ( P 50 ) Bottom 43
  • 44. ANDAMAN-NICOBAR LEAD ST3 ANDA W AN-99-15 E ST6 MAN ~ ~ ~~ ~ ~ ~~ ~ 4200 4000 3800 3600 3400 3200 ~ ~ ~~ ~ ~~ ~ ~ 1.6 CMP ST1 TWT IN SEC. ST4 3297 & 2.0 ST5 ST2 ANDAMAN ~ ~ ~~ ~ ~ ~~ ~ 2.4 N I 2.8 C O ~ ~ ~~ ~ ~ ~~ ~ ST3 OFFSHORE ~~~ ~~~ ~~ ~ B A 3.2 SEISMIC SECTION R ~ 4200 4000 3800 3600 3400 3200 ~~ ~ ~~ ~ ~ W E ~ I S 1.6 CMP TWT IN SEC. L A AN-99-15 CMP 3297 Vp 3297 3500 2.0 N D 3000 2500 S 2.4 2000Vp 2.8 1500 1000 B 3.2 S 500 R 0 1000 3000 5000 7000 9000 1100 1300 1500 1700 0 2000 2200 2400 2600 2800 3000 3200 REFLECTION STRENGTH Time 44
  • 45. NEW INITIATIVES ASSAM - ARAKAN BASIN SYLHET EXPOSED ANTICLINES 00 KAILASTILA A S S A M 19 00 1 ROKHIA 17 00 2 TICHNA BEAN BAZAR 15 ASSAM FENCHUGANJ 3 GOJALIA 0 270 PATHA RIA HAG-1&2 4 TULAMURA TR14-06 0 24 00 220 240 RASHIDPUR 21 00 5 BARAMURA 0 6 ATHARAMURA 10 CHAMPABARI HARARGAJ 7 LANGTARAI HABIGANJ 12 MIZORAM ONLAND 8 BATCHIA BAL TITAS 8 2150 2000 170 9 MACHLITHUM 2200 M I Z O R A M AGARTALA KHU 0 10 HARARGAJ DOME SAKHAN 7 911 13 11 HIA KH–1&1A 20 12 KHUBAL 00 14 BATC JAMPAI 1 6 KH - 2 MANU SYN 13 5 BAKRABAD 0 SUBSUR. STR. 180ASSAM – ARAKAN BASIN 14 AGARTALA DOME 2 3 4 15 00 14 00 JAMPAI OIL & GAS FIELDS BANGLADESH SAKHAN I RA LANGTARA SY 00 HA 13N GAS FIELDS BEGUMGANJ LA 1100 U RM EXPOSED STRUCTURE SEMUTANG 0 20 KM I CONCEALED STRUCTURE FENI 0 5 km Scale DO AT Scale Unexplored large anticlines in NE India. Gas field structures of Bangladesh extend into India (Titas – Giant Gas field) 45
  • 46. AA-ONN-2002/2 (Manipur) FUTURE OPPORTUNITIES PLAY TYPES ASSAM-ARAKAN BASINFOLDED DUPLEX PROSPECTS, KHARKUBLEN ANTICLINE STRUCTURAL CONCEPTS : DEEP SEATED DUPLEX ZONES 10 km Ramos gas field (see East West AAPG Mem62, 1995), a big duplex traps gas KHARKUBLEN underneath a detached ANTICLINE fault-propagation fold: X just as we infer in RAMOS GAS FIELD X Y Mizoram2 Y46 0 20008 m 4000 The fold trends of northernmost 6000 Argentina, southern Bolivia are 8000 comparable in size and continuity, with FOLDED DUPLEX Assam-Arakan’s PROSPECT The huge sub-Andean anticlines of northern Argentina and Bolivia have a very similar structural style to the Mizoram / Tripura folds. Wildcats in Bolivia at Aguarague, San Antonio, Margarita have proved between 15-20 Tcf of gas in the past 4 years. Here, in the blue-outlined boxes we compare the Ramos field’s fold style with our prospective play on the Rengte section. Around 4-5 km depth there is potential for very large fields in Mizoram. 46
  • 47. MODEL FOR CAMBAY INVERSION NEW INITIATIVES STRUCTURES Time 1 Time 4 Side-stacking main channels go in the lows Time 2 Extension creates ONLAND local half-graben ....and a local pond depocentre Time 5 Time 3 Coals and shales blanketCAMBAY BASIN the topographic highs Inversion on black fault New Inversion Structural Related Plays Showing flanks of Highs have a better Reservoir Development & hold good HC Potential 47
  • 48. MODEL OF POSSIBLE SAND BODIES IN INVERSION STRUCTURE REGIME NEW INITIATIVES ONLAND B C D A RAJASTHAN BASIN NEW PLAYS : BETTER RESERVOIR DEVELOPMENT IN THE FLANKS DUE TO STRUCTURAL INVERSION. HIGHS ARE BALDED 48
  • 49. BIKANER-NAGAUR SUB-BASIN OVL’s ONGC’s GLOBAL FOOTPRINTSSEISMIC SECTION THROUGH NANUWALA WELL NANUWALA - 1 280 300 3320 340 360 380 400 420 440 460 480 500 520 540 VP 0.0 HANSERAN EVAPORITE TOP 0.5 INFRA CAMBRIAN Light Oil H4 DOLOMITES H3 JODHPUR TOP 1.0 H2 BASEMENT TD 1806 M H1 BLOCK RJ-0N-90/5 49
  • 50. OVL’s EXPLORATION ASSETS OVL’s PRODUCIBLE ASSETS VIETNAM SUDAN AREA BLOCK STAKE (%) 45% STAKE IN 2 OFFSHORE GAS FIELDS 25% STAKE (SQ.KM) CAPEX COMMITTED RS. 1000 CRS PLUS CAPEX RS. 1731 CRS SYRIA 24 60 3853 PRODUCTION 1.22 MMSCMD PRODUCTION 3 MMT PER YEAR PIPELINES & REFINERY RUSSIA (SAKHALIN) IRAQ 8 100 10,500 20% STAKE MYANMAR CAPEX RS. 7,700 CRS 20% STAKE (BLOCK A-1) NC-188 LIBYA 49 8646 OIL PRODUCTION BY END 2005 (UPTO 5 MTPA) AREA 3,885 SQ.KM NC-189 GAS PRODUCTION BY 2008 (10-15 MMSCMD) RESERVES 4 – 6 TCF IRAN FARSI OFF. 40 3,500 50
  • 51. Gas Hydrate Potential Areas in Indian Deep Offshore Estimated Resource : 1894 TCMGAS HYDRATES IN INDIA LEGEND HIGHLY PROSPECTIVE MODERATELY PROSPECTIVE LOW PROSPECTIVE FIELD LABORATORY 51
  • 52. N G H P R O A D M A P S H O W IN G C R IT IC A L IN F O R M A T IO N P A T H L A B O R A T A R Y R E S O U R C E D R IL L IN G P R O D U C T IO N F A C IL IT IE S E S T IM A T IO N E X IT IN G L A B . M A P P IN G – G H IN P U T M a y 2 00 1 B R A IN S T O R M IN G S E S S IO N – N O V 2 0 0 2 E A S T C O A S T W E S T C O A S T O N G C A R E A IN P U T F R O M IN T E R N A T IO N A L G A IL O IL C O O P E R A T IO N C O L L A B O R . - V E M A L L IK W E L L A R E A A R E AW IT H C S M , U S A , + V E M A R C H 20 02 A p r il 2 0 0 3 + V E + V E E M E R G E N C E O F P O S S IB L E M E T H O D (S ) F O R In v e s ti g a t io n o f S h a l lo w S e d im e n ts E X P L O IT A T IO N O F G A S in c lu d in g G r a v i t y c o r in g D e c . 2 0 0 3 COAL BED METHANE A c q u i s it io n / H ir in g o f P r e s s u r e F R O M G A S H Y D R A T E C o r e - T e m p . T e c h n o lo g y D E C . 2 00 3 a n d D e e p W a te r C o r in g D r ills h ip J u n e 2 0 04 D R IL L IN G F O R C O R IN G / L O G G IN G D e c. 20 0 4 M A P P IN G R E S U L T S N E W A R E A - ve M a rc h 2 0 0 5 + ve OPPORTUNITIES D E S IG N & C O N C E P T U L IS A T I O N E S T A B L IS H M E N T O F R E S O U R C E E S T IM A T IO N O F S E L E C T E D M E T H O D F O R N E W L A B O R A T O R IE S C o n f id e n c e le v e l – 9 0 % P IL O T F IE L D IM P L IM E N T A T IO N D e c. 20 0 5 M id 2 0 0 5 M id . 2 0 0 5 T E C H N O -E C H O N O M IC R E S O U R C E A P P R A IS A L - ve B R A IN S T O R M IN G D ec . 20 05 + ve P IL O T T E S T P R O D U C T IO N - ve 2 0 0 6 -0 7 + ve R E S E R V E E S T IM A T E S E N D 2 00 7 C O M M E R C IA L P R O D U C T IO N C R IT IC A L P A T H B e yo n d 2 0 08 N O T E : I. T im e fr a m e f o r d iffe r e n t g o a ls is in d ic a t iv e o n ly a n d m a y c h a n g e d e p e n d in g o n th e r e s u lts o f p la n n e d R & D a c tiv it ie s . II. B r a in s to r m in g w ill c o n tin u e to ta k e p la c e o n a r e g u la r b a s is d u r in g p r o d u c t io n r e la te d a c tiv itie s a n d t h e f ir s t b r a in s t o r m i n g s e s s i o n it s e lf w i ll ta k e p la c e in t w o p h a s e s i .e ., id e n ti f ic a t io n o f p r o d u c t io n p r o b le m s a n d s o lu ti o n o f t h e p r o b le m s . III. T h e p r o c e s s o f p r o d u c tio n o f g a s fr o m g a s h y d r a te is c o m p le te ly b a s e d o n r e s o u r c e e s tim a tio n a n d s u b s e q u e n t s u c c e s s o f d r illin g /c o r in g fo r p r o v in g th e p r e s e n c e o f g a s h y d r a t e s in In d ia n o ffs h o r e . 52
  • 53. GROWING NEED FOR COALBED METHANE MAJOR COAL & LIGNITE FIELDS EXPLOITATION IN INDIA OF INDIA GONDWANA COALFIELDS CBM AN ENVIRONMENT FRIENDLY Gondwana Coalfields Ref. Coalfield Coal Belt Ref. Coalfield Coal Belt 20 Tertiary Lignitefields No. No. n CLEAN FUEL Tertiary Coal / Lignite ta 1. Raniganj 8. Ib-valley is MAHANADI k China 2. Jharia DAMODAR 9. Talchir VALLEY a ENERGY BENEFIT OF OTHERWISE P Nep VALLEY BELT Delhi al 15 3. Bokaro 10. Satpura 19 BELT NARMADA 4. N. Karanpura 11. Wardha WASTE MATERIAL 14 BELT 18 r ma 5. Singrauli 12. Godavari PRANHITA 5 4 2 GODAVARI 17 6 an 6. Sohagpur SON 13. Birbhum 3 1 13 BELT REDUCTION OF EMISSION OF My 10 7 7 8 7. Korba VALLEY 14. Rajmahal 9 Kolkata BELT GREENHOUSE GAS 11 Mumbai 12 Bay Of TERTIARY COAL / LIGNITE FIELDS DEGASSIFICATION REDUCES Arabian Bengal Sea Ref. Coal/Lignite Field Ref. Coal/Lignite Field Andaman Nicobar UNDERGROUND MINING RISKS Chennai No. No. Islands 16 15. Assam-Meghalaya 18. Barmer-Sanchor CBM USE IN POWER STATIONS AND 16. Neyveli 19. Bikaner 17. Cambay 20. Jammu & Kashmir OTHER INDUSTRIES 53
  • 54. BLOCKS ON OFFER STATUS OF RECENTLY AWARDED CBM BLOCKS Tertiary ON OFFER (CBM – II) BLOCKS Lignitefields 20 UNDER SECOND ROUND n ta is OF BIDDING (CBM-II) Total area opened up for k 2575 Sq. Km.a China Coal / Lignite Fields exploration & productionP (8 Blocks) Ne 15 CBM Blocks Awarded of CBM Delhi Delhi pal n Block Name State Ref. Awarded ta is 7 14 China No. r 1. South Karanpura : SK-CBM-2003/II k 8 ma a 5 Ne 4 2 P Delhi pal A. Awarded through CBM-I Round an 17 6 2. North Karanpura : NK(WEST)-CBM-2003/II 13 My 9 Raniganj East West Bengal 1 EOL 4 10 7 3 1 Kolkata 21 37 8 3. Sonhat : SH (NORTH)-CBM-2003/II 3 7 6 Bokaro Jharkhand 2 ONGC-IOC Kolkata 4 r 9 ma 5 1 North Karanpura Jharkhand 3 ONGC-IOC 11 4. Satpura : ST-CBM-2003/II an 8 My Mumbai 2 Sohagpur East M.P. 4 RIL Mumbai 5. Wardha : WD-CBM-2003/II 5 Kolkata 12 Bay Sohagpur West M.P. 5 RIL 6 Of 6. Godavari Valley : GV(NORTH)-CBM-2003/II Mumbai B. Awarded on Nomination basis Arabian Bengal Sea Raniganj North West Bengal 6 ONGC-CIL Nicobar 7. Barmer : BS(1)-CBM-2003/II Arabian Bay Nicobar Chennai Jharia Jharkhand 7 ONGC-CIL Chennai Sea of 8. Barmer : BS(2)-CBM-2003/II Bengal C. Awarded through FIPB route Islands Chennai Islands 16 Raniganj South West Bengal 8 GEECL Andaman 9. Barmer : BS(3)-CBM-2003/II Andaman Total Resource : 457 BCM, Production Potential : 12 MMSCMD Total Resource : 393 BCM, Production Potential : 13.5 MMSCMD 54
  • 55. Thank You 55

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